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182-033
• • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,April 07, 2017 8:47 AM To: Juanita Lovett Cc: Dan Marlowe;samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#316-385/PTD: 182-033/Trading Bay Unit G-06RD Juanita, The AOGCC will withdraw the sundry#316-385 as requested below. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Juanita Lovett[mailto:jlovett@hilcorp.com] Sent:Thursday,April 06, 2017 9:54 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Dan Marlowe<dmarlowe@hilcorp.com> Subject:Withdraw Sundry#316-385/PTD: 182-033/Trading Bay Unit G-06RD Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to remove the current dual completion,clean out well to PBTD,re-perforate and run a new gas lifted completion. Regards, Juanita Lovett Operations/Regulatory Tech p®�� 1 Hilcorp Alaska,LLC �+ 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: Ilovett@hilcorp.com RBDMS uu MAY - ! 21117 1 of T� • • em THE STATE Alaska Oil and Gas of Conservation Commission Ittsr 333 West Seventh Avenue " : GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0„0, *'h'P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis % %, S OCT 3 1 206, Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU G-06RD Permit to Drill Number: 182-033 Sundry Number: 316-385 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /6)14— Daniel T. Seamount, Jr. Commissioner 14 DATED this 24-day of July, 2016. RBDMS L-L, JUL 2 9 2016 0 • • STATE OF ALASKA JUL 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ElPerforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 1:1Other Run New G/L ❑ Completion 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0- 182-033 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20073-01 • 7.If perforating: 8.Wel Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A' / Will planned perforations require a spacing exception? Yes CI No No❑ Trading Bay Unit G-06RD • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 • McArthur River Field/Middle Kenai G Oil and Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,000, 9,775 . 10,360 - 9,133 • 2,220 psi 10,360 N/A Casing Length Size MD TVD Burst CoNapse Structural 356' 26" 356' 356' Conductor 631' 16" 631' 631' 2,630 psi 1,020 psi Surface 3,036' 13-3/8" 3,036' 2,879' 3,090 psi 1,540 psi Intermediate Production 8,917' 9-5/8" 8,917' 7,732' 5,750 psi 3,090 psi Liner 2,491' 7" 11,000' 9,763' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubkm MD(ft): 9,947-10,682 - 8,724-9,451 LS 3-1/2"&2-7/8"&SS 3-1/2" 9.2#N-80&6.4#N-80&9.2#N-80 9,928&10,394&8,402 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): See Schematic / See Schematic 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/8/2016 Commencing Operations: OIL ❑ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarloweehilcorD.com Printed Name Stan W.Golis Title Operations Manager Signature Phone (907)777-8356 Date 7 I S 1 t b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity 0 BOP Test 11 Mechanical Integrity Test ❑ Location Clearance 0 Other: 4t 2 ✓00 p5-= &r tos t-- t- e--5 t.,a -w-s-f"-- h / S L,.,.- . RBDMS JUL 2 9 2016 Post Initial Injection MIT Req'd? Yes ❑ No 0 r y Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0-yo LI �1 izz L. APPROVED BY Approved by:01.1.- COMMISSIONER THE COMMISSION Date: .7 l Z�j' /- PP / `�1 K7 rid �01 .//Tc /0 7: 41 ,/,,_ 7 27-/4. Submit Form and Form 10-403 Revised 11/2015 I a o is olid for 12 months from the date of approval. Attachments in Duplicate S • Well Work Prognosis Well: G-O6rd Hilcorp Alaska,LLC Date: 07/25/2016 Well Name: G-06rd API Number: 50-733-20073-01 Current Status: Gas-Lift Producer Leg: Leg#2 (NE corner) Estimated Start Date: August 08,2016 Rig: Moncla 404 Reg.Approval Required? 403 Date Reg.Approval Received: Regulatory Contact: Juanita Lovett Permit to Drill Number: 182-033 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Trudi Hallett Office: 907-777-8323 Cell: 907-301-6657 Current BHP: -3,233 psi @ 9,087'TVD 0.356 psi/ft,(6.85 ppg)2008 SIBP Max.Expected BHP: -3,600 psi @ 9,450'TVD 0.381 psi/ft,(7.35 ppg)add perfs Maximum Potential Surface Pressure: 2,220 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) **Note this is a No-Flow Well(06/16/2006),Will not flow based on an expected oil and water gradient of 0.427 psi/ft Brief Well Summary G-06rd is a gas-lift dual string producer completed in the Hemlock and G-zones.There is a plug currently in the long string X-nipple.The short string is plugged up with scale and the G-zone is being produced up the long string. This work-over will remove the current dual completion cleanout the well to PBTD re- perforate, and run a new Gas-Lift completion. Procedure: 1. MIRU over G-06rd. 2. RU and pull lowest valve possible in each string or punch tubing and circulate hydrocarbons from well. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. 4. PU landing joint and make-up to tubing hanger. Circulate any hydrocarbons from the well. `� 5. Recover dual string completion and cleanout well to PBTD at 10,854' or refusal. 6. PU RIH withRTTS to 9,900' Pressure test casing to-1,500 psi and chart for 30 minutes. At i( Ccs4 7. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. 8. After detonation, circulate perf gas,confirm well is static, POOH. 9. RIH with gas-lift completion. 10. Run Gas-Lift completion with live valves.Space out and land completion. 11. Set Packer/Pressure test completion: • Pressure up and set packer • Test tubing against plug in X nipple to 2500#and chart for 30 minutes,/ • Test IA to 1,500 psi and chart for 30 minutes(This will pressure up tubing also). 12. Set BPV. NU tree,test same. 13. Schedule SVS testing and no-flow w/AOGCC as per regulations. Attachments: I � F/ew ` ±Ls tt r^e•- . ✓ J. 1. Well Schematic/Current 2. Well Schematic/Proposed _ 7...z7-R. ! 3. Wellhead Diagram/Current "1 4. Wellhead Diagram/Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form • • Trading Bay Unit •llGrayling Well G-06RD Hilcorp Alaska,LL Completed 6-4-91 Casing Detail Size Wt Grade Thread ID Top Btm 26" Surf 356' IL j 16" 75 J-55 Butt 15.124 Surf 631' A 13-3/8" - 61 J-55 Butt 12.515 Surf 3,036' 9-5/8" - 47 N-80 Butt 8.681 Surf 79' 9-5/8" - 40 N-80 Butt 8.835 79' 4,005' 9-5/8" - 43.5 N-80 Butt 8.775 4,005' 6,642' Lc= 9-5/8" 47 N-80 Butt 8.681 6,642' 8,418' 631' 9-5/8" 47 P-110 Butt 8.681 8,418' 8,917' t 7" 29 N-80 Butt 6.184 8,509' 11,000' Tubing Detail Size Wt Grade Thread ID Top Btm Long String g 3-1/2" 9.2 N-80 Butt(SP CL) 2.992 Surf 9,928' 2 2-7/8" 6.4 N-80 Butt(SP CL) 2.441 9929' 10,394' 1 3036' L Short String HOWCO DV Collar 3-1/2" 9.2 N-80 Butt(SP CL) 2.992 Surf 8,402' 4218' Jewelry Item Depth ID OD Length Description LONG STRING 1 318 I 2.75 I 4.27 I 2.65 I Otis WLR SSSV Nipple 2 PTA"DSO"Gas Lift Mandrels GLM#1 2,874 2.92 5.43 6.6 PTA DSO GLM#2 4,764 2.92 5.43 6.6 PTA DSO GLM#3 5,872 2.92 5.43 6.6 PTA DSO C GLM#4 6,904 2.92 5.43 6.6 PTA DSO 3 I • I GLM#5 7,623 2.92 5.43 6.6 PTA DSO GLM#6 8,273 2.92 5.43 6.6 PTA DSO D 3 8,329 2.75 4.3 3.87 Otis"XA"SSD 4 >< y y 8,352' 4 8,361 2.992 8.347 17.82 Baker Twin Seal Pkr / / 5 9,928 2.441 3.9 0.69 X0 3-1/2"X 2-7/8" 1� E 6 9,929 10,283 2.441 3.5 354.02 Blast its,Steel 7 2.313 3.75 3.33 Otis"XA"SSD F 8 10,318 4.47 10.22 Locator Seal Assy 9 10,306 4 5.85 12.23 Otis"BWH"pkr w/7.7'SBE 10 10,360 2.313 3.25 1.32 Otis"X"Nipple X X 8,509' 11 10,394 2.441 3.75 0.8 WLEG MS SHORT STRING A. 316 I 2.75 I 4.27 I 2.65 I Otis WLR SSSV Nipple L Window Cut B. PTA"D50"Gas Lift Mandrels GLM#1 2,813 2.92 5.43 6.6 PTA DSO 8,917'-8,945' GLM#2 4,510 2.92 5.43 6.6 PTA DSO M 5 GLM#3 6,025 2.92 5.43 6.6 PTA DSO I GLM#4 6,700 2.92 5.43 6.6 PTA DSO GLM#5 7,254 2.92 5.43 6.6 PTA DSO I GLM#6 7,809 2.92 5.43 6.6 PTA DSO 6 = GLM#7 8,297 2.92 5.43 6.6 PTA DSO - C. 8,313 2.75 4.3 3.87 Otis"XA"SSD - D. 8,352 2.992 8.347 17.82 Baker Twin Seal Pkr E. 8,400 2.205 3.25 0.57 Otis"XN"Nipple AD 7 F. 8,402 2.441 3.25 0.57 WLEG 8 9 E t 10,306' PERFORATIONS Zone Top Bottom Amount SPF Last Present 4/27/08 10 Date Condition II - Initiated production from long string(shut-in since - G-2 9,947 9,972 25 1999 Open 1/99). Scale and stuck safety valve in short string G 3 10,014 10,046 32 1999 Open prevented continued production from the short 1/6/99 - G-4 10,072 10,105 33 1999 Open string. Ran Plug in"X" - Nipple @ 10,360' _ G-5 10,172 10,227 55 1999 Open 12/9-22/99 HB-1 10,368 10,400 32 Isolated - HB-2 10,421 10,441 20 Isolated Reperforated"G"Zone thru blast joints(#6) Fill n 10,665'W M in long string. HB-4 10,562 10,682 120 Isolated 9,947'-9,972',10,014'-10,046', / ` 10,072'-10,105',10,172'40,227' PBTD 10,854' REVISED BY:DEM 2015-03-05 • Trading Bay Unit PROPOSED Grayling Platform Well G-06RD ' Hilcoru Alaska,LL Completed: Future Casing Detail Size Wt Grade Thread ID Top Btm 26" Surf 356' 16" 75 J-55 Butt 15.124 Surf 631' 13-3/8" 61 1-55 Butt 12.515 _ Surf 3,036' r 9-5/8" 47 N-80 Butt 8.681 Surf 79' 9-5/8" 40 N-80 Butt 8.835 79' 4,005' _ 9-5/8" _ 43.5 _ N-80 Butt 8.775 4,005' 6,642' 9-5/8" 47 N-80 Butt 8.681 6,642' 8,418' 9-5/8" 47 P-110 Butt 8.681 8,418' 8,917' 7" 29 N-80 Butt 6.184 1 8,509' 11,000' Tubing Detail Size Wt Grade Thread ID Top Btm L . ...631' 3-1/2 ±9,640' JEWELRY DETAIL Item Depth(MD) Depth(TVD) ID OD Description Tubing Hanger 1 1 1 ±2,508' ±2,400' GLM 3036' 2 ±4,402' ±4,000' GLM 3 ±5,632' ±5,000' GLM 2 1 Howcoov 4 ±6,519' ±5,700' GLM Collar 4218' 5 ±7,138' ±6,200' GLM 6 ±7,726' ±6,700' GLM 3 7 ±8,294' ±7,200' GLM 8 ±8,766' ±7,600' GLM 4 FAu9 ±9,205' ±8,000' GLM 10 ±9,550' ±8,336' GLM-Orifice 11 ±9,600' V ±8,384' Packer 5 is -ill , 12 ±9,630' ±8,414' X-Nipple 13 ±9,640' ±8,423' WLEG 6 .1)) 7 L h) Perforation Detail Zone (Mp) Btm(MD) TOP(TVD) Btm(TVD) Amt Date Status 8 i hl G-1 ±9,723' ±9,737' ±8,504' ±8,518' ±14' Future G-1 ±9,747' ±9,753' ±8,528' ±8,533' ±6' Future G-1 ±9,791' ±9,847' ±8,571' ±8,626' ±56' Future X 9 k u ��' 8,509' G-2 ±9,946' ±9,974' ±8,723' ±8,751' ±28' Future G-2 9,947' 9,972' 8,724' 8,749' 25' 1999 Open 10 1 fit , G-3 _±10,013' ±10,045' ±8,789' ±8,821' ±32' Future 11 Window Cut G-3 10,014' 10,046' 8,790' 8,822' 32' 1999 Open 12 X 8,917'4,945' G-4 ±10,070' ±10,108' ±8,845' ±8,883' ±38' Future 3tih G-4 10,072' 10,105' 8,847' _ 8,880' 33' 1999 Open G-5 ±10,171' ±10,227' ±8,945' ±9,001' ±56' Future G-5 10,172' 10,227' 8,946' 9,001' 55' 1999 Open HK-1 _ 10,368' 10,400' 9,140' _ 9,172' 32' Isolated HK-1 ±10,368' ±10,403' ±9,140' ±9,175' ±35' Future HK-2 ±10,416' ±10,472' ±9,188' ±9,244' ±56' Future HK-2 10,421' 10,441' 9,193' 9,213' 20' Isolated HK-2 ±10,502' ±10,516' ±9,273' ±9,287' ±14' Future HK-3 ±10,528' ±10,541' ±9,299' ±9,312' ±13' Future HK-3-4 ±10,548' ±10,682' ±9,319' ±9,451' ±134' Future HK-4 10,562' 10,682' 9,333' 9,451' 120' Isolated HK-5 ±10,700' ±10,738' ±9,469' ±9,506' ±38' Future HK-5 ±10,743' ±10,795' ±9,511' ±9,562' ±52' Future / HK-5 ±10,799' ±10,818' ±9,566' ±9,585' ±19' Future HK-6 ±10,835' ±10,883' ±9,601' ±9,648' ±48' Future PBTD=10,854' TD=11,000' REVISED BY:JLL 2016-07-22 • 0 Grayling Platform • IIG-O6RD Current 03/20/2015 llilrnrp tlar'ka.1.11, Grayling G-06rd Tubing hanger,dual,CIW- 133/8X95/8X31/2X DCB, 115MX3% EUE8rdlift 3 1/2 X 31/2 IBT bottom,w/3"type _ H BPV profile, 1/8 non cont C� control line ports in hangers r.ir�r rw�.r II ill Tree assy, dual block, CIW-F, 1 I I 11 5M X 3 1/8 5M X 3 1/8 5M, prepped on it,�,^ 5 3/64 center, 3" CIW seal - '�•/� pockets, 1/2 npt control line ' Illic -IMilk O 1;3 _ exits °' SAI 1 0 j4iini (1\ ---- /I\ Tubing head,CIW-DCB, 1!I qii1 Valve,CIW-F, 2 1/16 5M FE, 135/83MX115M,w/2- HWO,AA 2 1/16 5M SSO,X-bottom -, I i' i, �� prep I 7 O r 01 it-ir" i trfticilt . - an 1■1 all E e. Casing head, Shaffer KD, all 135/83MX ISI liil 13 3/8 SOW,w/2-2" _ 2"LP CIW ball valve LPO, Ili I 1 :61 II.. .• i • •• Grayling Platform G-06RD Proposed 07/24/2016 I I YIi'rwrIi.t Inrka.l.J.( Grayling Tubing hanger,CIW-DCB- G-06rd FBB,11 X 3'A EUE 8rd lift X 13 3/8 X 9 5/8 X 3 1/2 susp,w/3"type H BPV,1/2 npt continuous control line, 6.25"extended neck prep Tree cap,Bowen,3 1/8 5M FE X 3"Bowen Quick Union uuiM n Valve,Swab,WKM-M, sot um 3 1/8 5M FE,HWO, U ,. 6 ..: DD trim '�,' V Valve,Wing,WKM-M, 3 1/8 5M FE,w/15" 4411's jiiliel m OMNI operator,DD trim i i i Cross,stdd,3 1/8 5M X 1 I 3 1/8 5M I i OO i 9 i i MEN mm uI uil Valve,Upper Master, WKM-M,3 1/8 5M FE,HWO, U '' DD trim 0) 4.4 mui unu MEM m_i i.., Valve,Master, '� U C• WKM-M,3 1/8 5M FE,HWO, p/,---- DD trim CEJv .`. i rR rq / ,, Tubing head,CIW-DCB, zip u:.= 13 5/8 3M X 11 5M,w/2- �,r — I� ISI Valve,WKM-M,2 1/16 2 1/16 5M SSO,X-bottom ` 5M FE,HWO,AA prep i, 1I ° ,' i II.WC)oiif ll' I-1-= 0 0,0 iiiI III g' R ' Casing head, Shaffer KD, III— ' III 13 5/8 3M X le 13 3/8 SOW,w/2-2" 0rill a'' X04.: LPO, ! • • Grayling Platform • H2016 BOP Stack Moncla 05/13/2016 Ililrarp:Unnko.W. 4.54' \ [9 Hy& '' -)_ GK 13 5/8-5000 , `sn r1I iii iii I I Bill ail I 2 7/8-5.s Shaffer SL variables 2.83' a [i,., 13 5/8 SM _Q1 5P1 , _ Blinds -00 • 0 Choke and Kill valves 2 1/16 5M 2.26' s,40111111%, � -+ i Mud Cross 1 r �_ -.r ' i .,'41/165MEF0 -N { �'Ii 3 I11 1!i Il11�1.1 l'a' iiia let I!' Ill ISI int Riser 13 5/8 5M FE X 13 5/8 5M FE 14.20' 111111 Spacer spool I#I III III IPI I I 135/85M FE X115M 2.75' Iii 'llt'lit Ill lit • • A 0;C) :j") C C o r -1 0D > c� X -1Zi1 �> cn w m r < � Oc � m x - M r r r N C� ZO * D X 0 m X n D X 2 O C U) D D —IG) O � � H C c Sco CD W_ mI Z o 0 z 0) H D z 0 _m v m Cl) -1 co D O L p _ P .1D�1N ramminumicas mil 'm ; X n C I— _ c Z F.-5 0 z c� Nu Nu 0Z TI �N oi W O O r _ m Z > Z � D ,nn r c r r r N Z -2, -0 * -1 0o ° I _ C c z �� v0 D m� I Z o Z Z C I— >D 0) H D Z 0 m m-0— a)a) m n -0 Eg±riiii — •41-1Drof , . 41 m , tn p O (1171.- � O m -nO < M O D n m Nu ii =D wok =c OZ ' W O'o c m m� mx .0 Lam: :■f-1 r mz mo- w - On - (P .Nu 00Nu Nu J co N II II ,, i 3 3 O m n O O_9 a a m 3a a a a a a a a T x -s° a:, c c 9 v a c a a n 0 0 0 0 0 0 0 0 0 0 0 A - 3 3 3 3 3 E m m non m m m m m m m "D r° 3 3 3 3 n 3 3 3 3 3 3 3 3 j ,1N r w T Fr j N J J J J J p � J J J J J J J J J N n 0 0 0 0 0 0 0 0 0 0 0 S 0 0 0 0 0 a a a a a a a W a a 0 a a a a a FJ to 00 N 01 to A N (D N A W N n n n n n n n n n v v 0 0 0 t3D W 3 031 Ln A w N 3ro t3/t A W N 3 O 0 000000000000 ono 0 O n O n O • Moncla Rig 404 • BOP Test Procedure Wear!)Alaska,1.I.c Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump,(monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) i • Moncla Rig 404 • BOP Test Procedure Hileorp alacka,1.1.1 Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1st valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open 1st valve of standpipe, close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross, close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to 1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLCAttachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed (e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized,record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • 0 @ J 2 CD /7 C co 0 / q2 a co 01 4Z ° q 5 D 5 / / ° CA ma -. co -0 / ƒ a) J Et 0 — Co 5W k A E w CD § 0 $ 9 0 3 \ z CD Q Kk 0 m ■ / « W § a CD Cl) 0 tQ Q � � � @ xi co E a) / J § ii Q o. CD o a) f Q 0 / 7 0 e a a)-0 , 2 = 0 CCD -, 2 C "t a > D f= 0 / / / co — Q. 0) * a) Ca 04 // k / / CD-I 2 O / * co » / k CD -<2C.70 // * n v v 2a) a) ilt DO « FDP % w %' § / f § _ I / o /�� X 7k • a E § "63a • D - /. . 2 I § / / m Go co ] D 01 § X20 \ B• o R q \ § zu— 0 / O• C2 CD ftZ � a • • Schwartz, Guy L (DOA) R DC) 5- From: Schwartz, Guy L(DOA) Sent: Wednesday, February 24, 2016 12:54 PM To: 'Juanita Lovett'; Dan Marlowe Cc: samantha.carlisle@alaska.gov Subject: RE: Please withdraw Sundry# 315-189/ PTD: 182-033 - Grayling G-06RD Juanita, Sundry 315-189 will be withdrawn as requested. Guy Schwartz Ec) JUN 2 8 2-C/162-C/16Sr. Petroleum Engineer SCt AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Juanita Lovett [mailto jlovett@ hilcorp.com] Sent: Wednesday, February 24, 2016 12:34 PM To: Schwartz, Guy L (DOA); Dan Marlowe Subject: Please withdraw Sundry # 315-189/ PTD: 182-033 - Grayling G-06RD Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jlovett@hilcorp.com 1 RBDMS LL FEAR 2 5 2016 //7/ THE STATE Alaska Oil and Gas _ � °fALAS}(A Conservation Commission � —--=` — 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax. 907 276.7542 www.aogcc.alaska.gov Dan Marlowe ' `� — 0 3 3 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pools, TBU G-06RD Sundry Number: 315-189 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .4111V Daniel T. Seamount, Jr. Commissioner DATED this ' day of April, 2015 Encl. RECEIVED . STATE OF ALASKA AR 3 I 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION „ �n� • APPLICATION FOR SUNDRY APPROVALS A`1 V 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate[. Pub Tubing 0 . Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Install ESP Cl ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC - Exploratory ❑ Development 182-033 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20073-01 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A>r Will planned perforations require a spacing exception? Yes ❑ No 0 / `Trading Bay Unit/G-06RD- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 • McArthur River Field/Middle Kenai G Oil and Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): ' 11,000 ' 9,775 -10,854 • 9,620 10,854 10,665 Casing Length Size MD ND Burst Collapse Structural 356' 26" 356' 356' Conductor 631' 16" 631' 631' 2,630 psi 1,020 psi Surface 3,036' 13-3/8" 3,036' 2,879' 3,090 psi 1,540 psi Intermediate Production 8,922' 9-5/8" 8,917' 7,732' 5,750 psi 3,090 psi Liner 2,491' 7" 11,000' 9,763' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic • See Schematic LS 3-1/2"&2-7/8"&SS 3-1/2" 9.2#N-80&6.4#N-80&9.2#N-80 9,928'(MD)8,705'(TVD)& 10,394'(MD)9,166'(ND)& 8,402'(MD)7,279'(ND) Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): See Schematic See Schematic I 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/15/2015 Commencing Operations: Oil 0• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe©hilcorp.com Printed Name Daan/n Marlowe / Title Operations Engineer Signature !��e'�1J ?4_% _ _Phone (907)283-1329 Date 3/30/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: —/ 31 —14361 Plug Integrity I=1 BOP Test L1V Mechanical Integrity Test ❑ Location Clearance ❑ Other: 2 �v �- &)/1 �C f (N�4 S P L /t p s ,.) •-- 4' Spacing Exception Required? Yes ❑ No 12" Subsequent Form Required: I Q 41 a LI 1 r / APPROVED BY I I Approved by: ` �/ COMMISSIONER THE COMMISSION Date: r; q-6•.1 S� I( • n � AM? –1"' Submit Form and Form 11 13(Revised 10/2012) Approved appllcatloGvR 1,6414 he date of approval. Attachmen ' Duplicate ' ` •4 4/7,75 RBDMS APR - 9 2015 Well Work Prognosis Well: G-06rd • Hileorp Alaska,LLC Date: 03/27/2015 Well Name: G-06rd API Number: 50-733-20073-01 Current Status: Gas-Lift Producer Leg: Leg#2 (NE corner) Estimated Start Date: May 15, 2015 Rig: HAK#1 Reg.Approval Required? 403 Date Reg.Approval Received: Regulatory Contact: Juanita Lovett Permit to Drill Number: 182-033 First Call Engineer: Dan Marlowe Office:907-283-1329 Cell:907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell:985-867-0665 Current BHP: —3,233 psi @ 9,087'TVD 0.356 psi/ft,(6.85 ppg)2008 SIBP survey Mid-Perf Max. Expected BHP: "'3,600 psi @ 9,450'ND 0.381 psi/ft,(7.35 ppg)add G&Hemlock perfs Max.Possible SP: 0 psi Well will not flow based on an expected oil?^d water gradient of 0.437 psi/ft 3t;a - '145 ��.�> r_s Brief Well Summary G-06rd is a gas-lift dual string producer completed in the Hemlock and G-zones.There is a plug currently in the long string X-nipple.The short string is plugged up with scale and the G-zone is being produced up the long string. This work-over will remove the current dual completion cleanout the well to PBTD re- perforate, and run an ESP completion. Procedure: 1. RU HAK Rig 1 over G-06rd. 2. RU and pull lowest valve possible in each string or punch tubing and circulate hydrocarbons from well. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOPAS equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. j) l � 4. PU landing joint and make-up to tubing hanger. Circulate any hydrocarbons from the well. 5. RU and cut long string below GLM#4 at 6,904'do not go below 7,020' due to tubing integrity 6. RU and cut short string as deep as possible 7. POOH laying down dual completion. 8. Fish remaining tubing one string at a time down to top of upper production packer at 8,352'. 9. Mill out and recover upper production packer. 10. Fish long string down to top of lower production packer at 10,306'. 11. Cleanout to top of production packer at 10,306' 12. PU RIH with RTTS to 9,900' Pressure test casing to—2,500 psi and chart for 30 minutes. 13. Remove production packer at 10,306'and cleanout well to PBTD at 10,854' 14. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. 15. After detonation, circulate perf gas,confirm well is static, POOH. 16. Run ESP completion. 17. Set BPV. NU tree,test same. 18. Schedule the no flow AOGCC within 2 weeks of stable production as per regulations. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack Trading Bay Unit Grayling Well G-06RD lli!carp Alaska,LL Completed 6-4-91 Casing Detail Size Wt Grade Thread ID Top Btm 1i,‘ 26 Surf 356 16" 75 J-55 Butt 15.124 42.60 631.00 13-3/8" 61 J-55 Butt 12.515 38.00 3035.71' 4=1 L=ki 9-5/8" - 47 N-80 Butt 8.681 37.00 78.80 9-5/8" 40 N-80 Butt 8.835 78.80 4004.61 9-5/8" 43.5 N 80 Butt 8.775 4004.61 6642.08 631' 9 5/8" 47 N-80 Butt 8.681 6642.08 8418.40 9 5/8" 47 P 110 Butt 8.681 8418.40 8917' 7" 29 N-80 Butt 6.184 8509' 11,000' Tubing Detail a-r l Size Wt Grade Thread ID Top Btm L[] L� Long String 2 B 3-1/2" 9.2 N-80 Butt(SP CL) 2.992 Surf 9928' L . 3236' 2-7/8" 6.4 N-80 Butt(SP CL) 2.441 9929' 10,394' Short String HOWCO DV Collar 3-1/2" 9.2 N-80 Butt(SP CL) 2.992 Surf 8402' 4218' L i=ij Jewelry Item I Depth 1 ID 1 OD I Length I Description LONG STRIN 1 318 I 2.75 I 4.27 I 2.65 I Otis WLR SSSV Nipple 2 PTA"DSO"Gas Lift Mandrels GLM#1 2,874 2.92 5.43 6.6 PTA DSO GLM#2 4,764 2.92 5.43 6.6 PTA DSO q V'..: GLM#3 5,872 2.92 5.43 6.6 PTA DSO v GLM#4 6,904 2.92 5.43 6.6 PTA DSO Ll ( GLM#5 7,623 2.92 5.43 6.6 PTA DSO 3 • I • GLM#6 8,273 2.92 5.43 6.6 PTA DSO I) 3 8,329 2.75 4.3 3.87 Otis"XA"SSD 4 >< X X 8,352' 4 8,361 2.992 8.347 17.82 Baker Twin Seal Pkr 5 9,928 2.441 3.9 0.69 XO 3-1/2"X 2-7/8" i F 6 9,929 2.441 3.5 , 354.02 Blast Jts,Steel 7 10,283 2.313 3.75 3.33 Otis"XA"SSD F C 8 10,318 4.47 10.22 Locator Seal Assy 9 10,306 4 5.85 12.23 Otis"BWH"pkr w/7.7'SBE V 10 10,360 2.313 3.25 1.32 Otis"X"Nipple L1. X 8,509' 11 10,394 2.441 3.75 0.8 WLEG MS SHORT STRING A. . 316 I 2.75 I 4.27 I 2.65 I Otis WLR SSSV Nipple L , Window Cut B. PTA"DSO"Gas Lift Mandrels GLM#1 2,813 2.92 5.43 - 6.6 , PTA DSO 8,917'-8,945' GLM#2 4,510 2.92 5.43 6.6 PTA DSO 5 GLM#3 - 6,025 2.92 5.43 6.6 PTA DSO - GLM#4 - 6,700 2.92 5.43 , 6.6 , PTA DSO GLM#5 7,254 2.92 5.43 6.6 PTA DSO = GLM#6 _ 7,809 , 2.92 5.43 6.6 PTA DSO 6 - GLM#7 8,297 - 2.92 5.43 6.6 , PTA DSO C. 8,313 2.75 4.3 - 3.87 - Otis"XA"SSD - D. . 8,352 2.992 8.347 - 17.82 - Baker Twin Seal Pkr = E. 8,400 2.205 3.25 0.57 _ Otis"XN"Nipple t+a 7 F. 8,402 2.441 3.25 0.57 WLEG 8 9 g 10,306' to PERFORATIONS 4/27/08 11�- Initiated production from long string - Last Present (shut-in since 1/99). Scale and stuck Zone Top Bottom Amount SPF safetyvalve in short stringprevented 1/6/99 - Date Condition - , continued production from the short Ran Plug in"X" - G-2 9,947 9,972 25 1999 Open string. Nipple @ 10,360' _ G-3 10,014 10,046 32 1999 Open G-4 10,072 10,105 33 1999 Open 12/9-22/99 Reperforated"G"Zone thru blast Fill @ 10,665'WLM G-5 10,172 10,227 55 1999 Open 40.1 HB-1 10,368 10,400 32 Isolated joints(#6)in long string. 9,947'-9,972',10,014'-10,046', PMD 10,854' HB-2 10,421 10,441 20 Isolated 10,072'-10,105',10,172'-10,227' HB-4 10,562 10,682 120 Isolated - REVISED BY:DEM 2015-03-05 Trading Bay Unit PROPOSED Grayling Platform Well G-06RD Hilcorp Alaska,LL Completed: Future Casing Detail Size Wt Grade Thread ID Top Btm 26 Surf 356 16" 75 J-55 Butt 15.124 42.60 631.00' mmimimiii ., 13-3/8" 61 J-55 Butt 12.515 38.00 3035.71' 9-5/8" 47 N-80 Butt 8.68.1 37.00 78.80 9-5/8" 40 N-80 Butt 8.835 78.80 4004.61 9-5/8" 43.5 N-80 Butt_ 8.775 4004.61 6642.08 9-5/8" 47 N-80 Butt 8.681 6642.08 8418.40 9-5/8" 47 P-110 Butt 8.681 8418.40 8917' 7" 29 N-80 _ Butt 6.184 8509' 11,000' Tubing Detail Size Wt Grade Thread ID Top Btm '631' 3-1/2" 9.2 L-80 burl JEWELRY DETAIL Item Depth ID OD Description Tubing Hanger ,3036' - r awcoov ±8,400' Bottom of ESP LCdiar R16 Perforation Detail Zone Top(MD) Btm(MD) TOP(ND) Btm(TVD) Amt Status G-1 ±9,904' , ±9,913' ±8,682' ±9' Future G-2 9,947' 9,972' 8,724' 8,749' 25' G-2 ±9,950' ±9,969' ±8,727' ±8,746' ±19' Future G-3 10,014' 10,046' 8,790' 8,822' 32' 1 G-3 ±10,030' ±10,043' ±8,806' ±8,819' ±13' Future flux", G-4 10,072' 10,105' 8,847' 8,880' 33' G-4 ±10,075' ±10,102' ±8,850' ±8,877' ±27' Future G-5 10,172' 10,227' 8,946' 9,001' 55' 1 G-5 ±10,175' ±10,226' ±8,949' ±9,000' ±51' Future X HK-1 10,368' 10,400' 9,140' 9,172' 32' X 8,509' ±27' Future HK-1 ±10,371' ±10,398' ±9,143' ±9,170' HK-2 ±10,419' ±10,465' ±9,191' ±9,237' ±46' Future L Window Cut 8,917'4,945' HK-2 10,421' 10,441' 9,193' 9,213' 20' HK-2 ±10,507' 4 ±10,515' ±9,278' ±9,286' ±8' Future HK-3 ±10,525' 4 ±10,572' ±9,296' ±9,343' ±47' Future ME ME HK-4 10,562' 10,682' 9,333' 9,451' 120' um HK-3 ±10,579' 4 ±10,599' ±9,350' ±9,369' ±20' Future HK-4 ±10,610' ±10,680' ±9,380' ±9,449' ±70' Future _ '- HK-5 ±10,700' ±10,720' ±9,469' ±9,489' ±20' Future HK-6 ±10,841' ±10,846' ±9,607' ±9,612' ±5' Future - Notes: AK 4/27/08-Initiated production from long string(shut-in since 1/99). Scale and stuck safety valve in short string prevented continued production from the short string. PBTD=10,854' TD=11,000' 12/9-22/99-Reperforated"G"Zone thru blast joints(#6)in long string. 9,947'-9,972',10,014'-10,046',10,072'-10,105',10,172'-10,227'. REVISED BY:JLL 2015-03-05 Grayling Platform G-O6RD Current .11 03/20/2015 Iliktirp %Ltd..,.LL( Grayling G-06rd Tubing hanger,dual,CIW- 133/8X95/8X31/2X DCB, 115MX3Y2EUE8rdlift 3 1/2 X 31/2 IBT bottom,w/3"type _ H BPV profile, 1/8 non cont ® 4 ® control line ports in hangers ■ter �.� Tree assy, dual block,CIW-F, 115MX31/85MX31/8 5M, prepped on 0 EV 5 3/64 center, 3" CIW seal E i ( -.- pockets,%npt control line II 0 iti exits �4, ,_ �frt im ..... i._____,„ - =411 I 1 11im= III I III Valve,CIW-F, 2 1/16 5M FE, Tubing head,CIW-DCB, 13 5/ 8 3M X 11 5M,w/2-2 1/16 _ - �■ HWO, AA 5M SSO,X-bottom prep ki ■Ali[ o ll► I -". iii I III - - III II I i it Casing head, INF Shaffer KD, 135/83MX III i III 13 3/8 SOW,w/2-2" ) , ® 2"LP CIW ball valve LPO, ISI �II�a 1 1 � - . Grayling Platform G-06RD Proposed II 03/20/2015 Hilrurp tlnrk:..I.i.(. Grayling Tubing hanger,CIW-DCB-ESP, G-06rd 11 X 3'A EUE lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 3"type H BPV profile,5'''A EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union a iii -111 ii, Valve,swab,WKM-M, ,.Q O _, o 3 1/8 5M FE,HWO, rc T-24 ,., ,,, Valve,WKM-M,3 1/8 5M FE,w/ 111=110 ,, MA-16 operator Valve,wing,WKM-M, 7-foj� 2 1/16 5M FE,HWO, lt,..4.,:O ��� 0I T-24 � li 41.11116 .1 pm"I II I e ar Valve,lower master,WKM-M, Z.ro( O o) 3 1/8 5M FE,HWO,T-24 e ® ''. :u illig n: ginb AIM Adapter,CIW-Toadstool,11 5M Stdd X 3 1/8 5M FE,prepped for 5'/ESP neck,2-'/2 npt continuous control line ports Tubing head,CIW-DCB, :oil i ii.. 13 5/8 3M X 11 5M,w/ I I i a I ii 2-2 1/16 5M SSO, Valve,WKM-M,2 1/16 5M FE, X bottom is It_� , -, 1 HWO,DD Ili I III Casing head, Ns Shaffer KD, III me I 1 I 13 5/8 3M X 2"LP OW ball valve 13 3/8 SOW,w/2-2" ' i "ME I s l • I. LPO, y Grayling Platform 2015 BOP Stack (HAK#1) .11 IHhir:ta.k.,LLr. 01/15/2015 Grayling Platform 2015 Workovers BOP Drawing(HAK#1) Quail Tool Rental Stack If/ . 11411 III Ii ill I'l I. III 3.42' Shaffer 11"5M I 1 111 1111 I I 111111111 III III !IMO- 4.54' 11„,, -,�In , , 111I 2.00' I r ' � - IIIO • rRIM; 11 Kill Side MIP- Choke side 1.00'to 2.00' 21/16 5M w/HCR and Unibolt line 2 1/16 5M w/HCR and Unibolt line connection TIM WI connection Drill deck Riser 11 5M FE X 16.00' 11 5M FE fi tftl_tftuft.[[ UIIvU��ll1 3.00' Spacer spool 11 5M FE X 11 SM FE I III III lIl 11 Hilcorp HAK#1 BOP Test Procedure Hilcorp Alaekn.1.1.: Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Hilcorp HAK #1, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure Hilcorp HAK#1 BOP Test Procedure • eacorp Alaska.1.1.(: Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-2 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. i Hilcorp HAK#1 BOP Test Procedure eaco.P:uask,.i,i.c Attachment#1 d) Open C-2. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3,4,9. After test, open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5&6, leave 9 closed. iv) Valves, 7,8,9. After test, open all valves. e) Close C-3. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test C-1, C-2, and C-4 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Ima ect Well History File Cover XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _~ ~z~-~)~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable), [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No~ype [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [3 Logs of various kinds NOTES: [] Other Project Proofing BY; OBIN Scanning Preparation VINCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,~ YES NO V,NC N S.ER ' MAR,A Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; /S/ General Notes or Comments about this file: Quality Checked {do.e) 12/lOl02Rev3NOTScanned.wpd • • Page 1 of 1 Regg, James B (DOA) From: Liebenthal, John W [LiebenthalJ @chevron.com] '1<e0 ( ( l( Y. January Sent: Friday, 28 , 2011 2:55 PM I To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Myers, Chris S; Johnson, Wayne E; Owen, Claude D Subject: RE: Revised well head safety report We will adjust the pilot, retest and send the results within the 24 hour time period or if not resolved, shut it ✓ in as instructed. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, January 28, 2011 2 :41 PM To: Liebenthal, John W; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) .%�� � Cc: Myers, Chris S; Johnson, Wayne E Owen, Claude D Subject: RE: Revised well head safety report Based on info provided, my calculations show that the pilot for G -06RD failed. Regulations require pilot to trip at 50% of separator pressure or 25% of flowing tubing presssure, whichever is greater. [see 20 AAC 25.265(h)(9)]. Required trip pressure for G -06RD was 55psi; reported values was 45psi. G -06RD must be shut in if situation cannot be resolved and LPS retested within 24 hours. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 FEB 1 21111 Anchorage, AK 99501 907 - 793 -1236 From: Liebenthal, John W [mailto:LiebenthalJ @chevron.com] Sent: Friday, January 28, 2011 1 :55 PM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Myers, Chris S; Johnson, Wayne E; Owen, Claude D Subject: Revised well head safety report Miss Brooks, Here is the revised reports as you have requested. I will use the new form you sent on future tests. Thanks Jon Liebenthal Lead Operator Grayling Platform (907) 776 -6630 mailto :Iiebenthalj @chevron.com 1/28/2011 • • SVS LPP Performance Test Evaluation Insp #: not witnessed Trading Bay Unit; Grayling Platform Date: 1/27/2011 Well PTD Pressure (psi) Test Code Separator ( Tubing I Req'd LPP Trip I Actual LPP Trip G -02RD 1820670 75 200 50 58 P G -06RD 18203 75 220 55 45 F G-0/ - row I 75 110 37.5 50 P G -12RD3 2020550 75 120 37.5 45 P G -13 1680610 75 140 37.5 52 P G -17RD 1780030 75 120 37.5 54 P G -18DPN 1831350 210 205 105 110 P G -20 1740100 75 180 45 50 P G -21 RD 1980640 75 100 37.5 50 P G -28RD 2000380 75 100 37.5 45 P G -32 1690860 75 180 45 50 P G -33 1700110 75 110 37.5 45 P • • Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Chevron Submitted By: Jon Liebentha Date: 1/27/2011 Operator Rep: Jon LiebenthaField/Unit /Pad: TBU Grayling Platform AOGCC Rep: . Separator psi: LPS 75 HPS 350 Well Permit Separ Set L/P Test Test Test Date Passed Retest Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Or Date Shut In GAS, CYCLE, SI G -01RD 1911390 G -02RD 1820670 75 55 58 P P OIL G -03RD2 1830100 G -04RD 1811830 G -06RD 1820330 75 45 45 P P OIL G -07 1680610 75 50 50 P P OIL G -08RD 1780450 G -12RD3 2020550 75 45 45 P P OIL G -13 1680570 75 50 52 P P OIL G -14 1680800 G -15RD 1980990 G -17RD 1780030 75 50 54 P P OIL G -18DPN 1831350 210 160 110 P P P GAS G -20 1740100 75 50 50 P P OIL G -21RD 1980640 75 50 50 P P OIL G -24 1760320 G -25 1760370 G -26RD 2001050 G -28RD 2000380 75 45 45 P P OIL G -30 1690470 G -31 1690720 G -32 1690860 75 50 50 P P OIL G -33 1700110 75 45 45 P P OIL G -34RD 1790130 Wells: 12 Components: 25 Failure 0 Failure Rate: 0.00% ❑ 90 Day Remarks: Due to weather AOGCC Rep could not make it. Instructed us to go ahead with test without him 18 Short is denoted on this sheet RJF 12/21/04 Page ] X10000081.xls • • Alaska Oil and Gas Conservation Commission Safety Valve System Test Well Pressures Report Operator: Chevron Submitted By: Jon Liebenthal Operator Rep: Jon Liebenthal Field/Unit /Pad: TBU Grayling Platform AOGCC Rep: . Date: 1/27/2011 Well Permit Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI PSI G -01RD 1911390 G -02RD 1820670 200 Yes G -03RD2 1830100 G -04RD 1811830 G -06RD 1820330 220 Yes G -07 1680610 110 Yes G -08RD 1780450 G -12RD3 2020550 120 Yes G -13 1680570 140 Yes G -14 1680800 G -15RD 1980990 G -17RD 1780030 120 Yes G -18DPN 1831350 205 No Dual string gas well -Short side G -20 1740100 180 Yes G -21RD 1980640 100 Yes G -24 1760320 G -25 1760370 G -26RD 2001050 G -28RD 2000380 100 Yes G -30 1690470 G -31 1690720 G -32 1690860 180 Yes G -33 1700110 110 Yes G -34RD 1790130 Remarks: Due to weather AOGCC Rep could not make it. Instructed us to go ahead with test without him. RJF 09/19/02 Page 1 of 1 X10000081.xls • Alaska Oil and Gas Conservation Commission Safety Valve System Test Well Pressures Report Operator: Chevron Submitted By: Jon Liebenthal Operator Rep: Jon Liebenthal Field/Unit/Pad: TBU Grayling Platform AOGCC Rep: Date: 1/27/2011 0 ' -1 g r R � " � ,_ i A Well Permit Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI PSI G -01RD 1911390 G -02RD 1820670 G -03RD2 1830100 G -04RD 1811830 G -06RD 1820330 G -07 1680610 G -08RD 1780450 G -12RD3 2020550 G -13 1680570 G -14 1680800 G -15RD 1980990 G -17RD 1780030 G -18DPN 1831350 265 No Dual string gas well -Long side G -20 1740100 G -21RD 1980640 G -24 1760320 G -25 1760370 G -26RD 2001050 G -28RD 2000380 G -30 1690470 G -31 1690720 G -32 1690860 G -33 1700110 G -34RD 1790130 Remarks: This file is for 18 Long RJF 09/19/02 Page 1 of 1 X10000080.xls • Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Chevron Submitted By: Jon Liebentha Date: 1/27/2011 Operator Rep: Jon LiebenthaField/Unit /Pad: TBU Grayling Platform AOGCC Rep: Separator psi: LPS 75 HPS 350 Well Permit Separ Set L/P Test Test Test Date Passed Retest Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Or Date Shut In GAS, CYCLE, SI G -01RD 1911390 G -02RD 1820670 G -03RD2 1830100 G -04RD 1811830 G -06RD 1820330 G -07 1680610 G -08RD 1780450 G -12RD3 2020550 G -13 1680570 G -14 1680800 G -15RD 1980990 G -17RD 1780030 G -18DPN 1831350 210 160 110 P P P GAS G -20 1740100 G -21 RD 1980640 G -24 1760320 G -25 1760370 G -26RD 2001050 G -28RD 2000380 G -30 1690470 G -31 1690720 G -32 1690860 G -33 1700110 G -34RD 1790130 Wells: 1 Components: 3 Failure 0 Failure Rate: 0.00% ❑ 90 Day Remarks: Due to weather AOGCC Rep could not make it. Instructed us to go ahead with test without him. This File is for 18 Long RJF 12/21/04 Page 1 X10000080.xls l~ J • ~~Q~~ Oo ~ Q~a~~a /,E..MA..,,~o~.~ June 16, 2010 Mr. Steve Lambert Sr. Advising Petroleum Engineer Union Oil Company of California P.O. Box 196247 . Anchorage, Alaska 99519-6247 ~ `: ~ 7~ ~#'' ~ ' ~ ~ 4 ."` d C~ `Ef Re: No Flow Status of TBU G-06RD PTD 1820330 McArthur River Field Dear Mr. Lambert: The Alaska Oil and Gas Conservation Commission (Commission) received your letter dated May 11, 2010 and has eviewed our files relating to the no-flow status of Trading Bay Unit (TBU) -06RD PTD 1 ~2Q33~ . You requested confirmation that a 2003 no- flow test is sufficient to maintain the no flow status of TBU G-06RD. The Commission agrees that the well has a valid no flow test allowing TBU G-06RD to produce without a subsurface safety valve. TBL' G-06RD is a dual string completion with the long string accessing the Hemlock formation and the short string accessing the Tyonek G formation. Union Oil Company of California (Union) reports that production testing in conjunction with production logs run in December 1998 found that the well made more fluid with the long string shut in. The evaluations further indicated that most of the Hemlock production was exiting the long string through a hole in the tubing at 8,627 feet and was being produced up the short string. A January 1999 decision by Union to produce the well up the short string involved isolating the Hemlock formation with a deep tubing plug and reperforating the Tyonek G zone. Union shifted Tyonek G zone production from the short string to the long string after repeated unsuccessful attempts in early 2003 to continue production through the well's short string (following a well shut in). The Commission witnessed a no flow test of this well configuration on April 16, 2003 (Hemlock zone isolated with tubing plug; short string incapable of flowing to surface; Tyonek G zone produced to surface through hole in long string). The passing test certified that the well - as configured -was not capable Mr. Steve Lambert ~ • June 16, 2010 Page 2 of unassisted flow of hydrocarbons to surface. The Commission approved no flow test allowed Union to eliminate the well's subsurface safety valve. The integrity of the plug installed in the longstring that isolates the Hemlock has been verified by static bottomhole pressure measurements, comparing the pressures measured in the open Hemlock in TBU G-24 and G-26 with the Tyonek G zone pressures in TBU G-06RD. The lower pressure measured in the Tyonek G zone confirm the Hemlock remains isolated. Therefore, the configuration of the well is the same as was tested in Apri12003 for no flow of fluids to surface. Should you have any questions about the Commission's findings, please contact Jim Regg at 793-1236. Sincerely, Daniel T. Seamount, Jr. Chair SVS Test Report Grayling Page 1 of 1 Regg, James B (DOA) • ~ l ~Z- p 3.~ From: Owen, Claude D [owenc@chevron.com] Sent: Tuesday, April 29, 2008 2:49 PM '"~ ~~~~~~ To: Regg, James B (DOA); Fleckenstein, Robert J (DOA) ~~~ Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W Subject: SVS Test Report Grayling Attachments: SVS TEST G-6L 4-27-08.x1s «SVS TEST G-6L 4-27-08.x1s» Gentlemen Please find attached the SVS test report for Chevron Grayling Platform well G-6RD. This is a dual string well in which the long string had been shut in for an extended period of time. The short side was tested on 4/04/08 during a state witnessed test but the long string was not in production at that time. The long string was brought back into production on 4/27/ 08. The SVS components were tested on 4/27/08. Thank you, Dave Owen Lead Operator Chevron Grayling Platform 907-776-6630 owenc@chevron.com ~~~~~ ~A~ ~ ~~~8 4/30/2008 A~a Oil and Gas Conservation Comm~n Safety Valve System Test Report Operator: Chevron Operator Rep: Liebenthal AOGCC Rep: 4/27/2008 350 i~i~~~ll Data Pilots S'SA' SSS6% Test/Rete.tt/SI Date {~'"e/1 T~~Pe Well Number Permit Number Separ PSI Set PSI L/P Trip Test Code Test Code Test Code Date Passed Retest Or Date Shut In o~i, waG, GINJ, Gas, CYCLE, SI G-O1RD 1911390 G-02RD 1820670 G-03RD2 1830100 G-04RD 1811830 G-06RD 1820330 75 50 60 P P OIL G-07 1680610 G-08RD 1780450 G-12RD3 2020550 G-13 1680570 G-14 1680800 G-15RD 1980990 G-17RD 1780030 G-18DPN 1831350 G-20 1740100 G-21 RD 1980640 G-24 1760320 G-25 1760370 G-26RD 2001050 G-28RD 2000380 G-30 1690470 G-31 1690720 G-32 1690860 G-33 1700110 G-34RD 1790130 Wells: Remarks: 1 Components: 2 Failures: 0 Failure Rate: 0.00% ^ 90 Day Long side of well had been shut-in for an extended period of time. Well was brought back t production on 4/27/08. Submitted By: Dave Owen Date: Field/LJnit/Pad: TBU Grayling Platf Separator psi: LPS 75 HPS RJF 12/21/04 Page 1 of 2 SVS TEST G-6L 4-27-08.x1s Grayling G 1~.~vl-c~ l~ vim? ~ C ~-U2~ ql~/ou Casing Detail Size Wt Grade ID Top Btm 16" 75 J-55 Surf 631' 9-5/8" 47 N-80 Surf 8922' 7" 29 N-80 8509' 11,000' 116199 Ran Plug in Nipple @ 10 Tubing Detail Size Wt Grade Thread ID Top Btm Lon Strin 3-1/2" 9.2 N-80 Butt 2.992 Surf 9928' ?-7/8" 6.4 N-80 Butt 2.441 9929' 10,394' Short Strin 3-1 /2" 9.2 N-80 Butt 2.992 Surf 8402' Jewelry Item Depth ID OD Len th Description LONG STRING 1 318 2.75 4.27 2.65 Otis WLR SSSV Nipple 4/27108 6.60 Initiated production from long string. 6.60 Scale and stuck safety valve in short 6.60 string prevented continued 6.60 production from the short string. 6.60 (Long string had been shut-in since 6.60 Jan 1999.) 3.87 Otis "XA" SSD T i S l Pk 17.82 w n ea r Baker 5 9928 2.441 3.9 .69 XO 3-1/2" X 2-7/8" 6 9929 2.441 3.50 354.02 Blast Jts, Steel 7 10,283 2.313 3.75 3.33 Otis "XA" SSD 8 10,318 4.47 10.22 Locator Seal Ass 9 10,306 4.00 5.85 12.23 Otis "BWH" kr w/ 7.7' S 10 10,360 2.313 3.25 1.32 Otis "X" Nipple 11 10,394 2.441 3.75 .80 WLEG MS SH ORT STRING A. 316 2.75 4.27 2.65 Otis WLR SSSV Nipple B. PTA "DSO" Gas Lift Mandrels GLM#1 2813 2.92 5.43 6.60 5 43 6 60 9_22/gg . 5.43 . 6.60 perforated "G" Zone thru blast 5.43 6.60 its in long string 5.43 6.60 . 947- 9 972 9 5.43 6.60 , , 014-10 046 0 5.43 6.60 , , 072 10 105 0 4.3 3.87 Otis "XA" SSD - , , 172 10 227 0 .347 17.82 Baker Twin Seal Pkr - , , 3.25 .57 Otis "XN" Nipple F. 8402 2.441 3.25 .57 WLEG PERFORATIONS Zone Top Btm Zone Top Btm G-2 9947 9972 HB-1 10,368 10,4( G-3 10,014 10,046 HB-2 10,421 10,4 G-4 10,072 10,105 HB-4 10,562 10,61 G-5 10,172 10,227 Grayling Platform SVS inspection follow up e e Ifélû33 Subject: Grayling PlatfomïSVSirtspection follow up From: "Ryan, James M" <ryanj@unocäl.Com> Date: Thu, 10 Nov 2005 21:19:17 ~0900 .' To:";' Jè)þnlt,:<Wf;lskij@unocal.com>NmJe ' in.~tåæ~àk.us ' ,:,.t¡i!:f:::'" , " CC: o,~oh1µ1yT" <santiagoj@unod~tcom , ,'Myers, Chris Sit ~nl "c@unot~ï.com>,:' eDit <owenc@unocal.comt, "or oOOson, Wayne I;~<:j,()hnsot\v@unocal.coIXl>' This letter is being sent as notification that the SSV was replaced on G-06 RD the new SSV was tested and passed and the well was brought back to production at 6:00 pm 11/10/06 Regards, James Ryan Lead Operator Grayling Platform 907/776/6630 ~i~,i" Íì.,¡Mi,,~'~YE\ 1ío:\¡i!{M;¡~t'í''ti¡;..· 4 . From: Waski, John Sent: Tuesday, November 08, 2005 4: 10 PM To: 'Jim_regg@admin.state.ak.us' Cc: Santiago, Johnny T; Myers, Chris S; Ryan, James M; Owen, Claude D; Johnson, Wayne E Subject: Grayling Platform SVS inspection follow up Date: Nov. 8th 2005 Re: Grayling Platform Nov. 7th SVS inspection follow up Dear Mr. Regg AOGCC inspector, Mr. John Crisp was onboard the Grayling platform to witness our SVS testing on Nov ih 2005. The SSV's on G-25 and G-06RD were found to be leaking. Both of these wells have a "No Flow" status. The following corrective actions have been taken. G-25 The SSV was replaced on 11/7/05, the new SSV was tested and passed. G-06 RD Well was shut in on 11/8/05, The SSV and flow line are scheduled to be replaced, Piping is in transit to the platform, baring weather delays, we are expecting the piping to be on board tomorrow 11/9/05. Piping and SSV will be changed at that time. G-06RD will be brought back on line following a satisfactory test of the new SSV. This will be communicated in a follow up email to you. We can accommodate a witnessed retesting of these valves any time that would work for you. If you have any questions please feel free to contact me. Regards, J.C. Waski Production Foreman Grayling Platform (907) 776-6632 I of 1 11/14/2005 8:38 AM ~...I.A.J .............0 Å ...1I..4."'....v............... OJ I ' ...., .l.J......~p"""""'..lvJ...... ....V..l....v v, "y e e \3d ~033 Sub.iect: Grayling Platf(mn SVS inspection J()lIow up \t) \0< From: "Waski, John" <waskU@unoca1.com> 1£1{l,1 ., Date: Tue, 08 Nov 2005 16:09:46 -0900 To: jimJcgg@admin.state.ak.us CC: "Santiago, Johnny T" <santiagoj@unocal.com>, "Myers, Chris S" <myersc@unoca1.com>, "Ryan, James M" <ryanj@unocal.com>, "Owen, Claude 0" <owenc@unocal.com>, "Johnson, Wayne E" <johnsonw@unocal.com> Date: Nov. 8th 2005 Re: Grayling Platform Nov. 7th SVS inspection follow up Dear Mr. Regg AOGCC inspector, Mr. John Crisp was onboard the Grayling platform to witness our SVS testing on Nov ih 2005. The SSV's on G-25 and G-06RD were found to be leaking. Both of these wells have a "No Flow" status. The following corrective actions have been taken. G-25 ¡/ / G-06 RD The SSV was replaced on 11/7/05, the new SSV was tested and passed. Well was shut in on 11/8/05, The SSV and flow line are scheduled to be replaced, Piping is in transit to the platform, baring weather delays, we are expecting the piping to be on board tomorrow 11/9/05. Piping and SSV will be changed at that time. G-06RD will be brought back on line following a satisfactory test of the new SSV. This will be communicated in a follow up email to you. We can accommodate a witnessed retesting of these valves any time that would work for you. If you have any questions please feel free to contact me. Regards, J.C. Waski Production Foreman Grayling Platform (907) 776-6632 ~NED DEC 1 ß Lí}D~ 1 of 1 11/8/20054:27 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich, Commissioner THRU: Regg/Maunder, P. I. Supervisor DATE: April 16, 2003 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector No-Flow Test Unocal Grayling G-6RD (short) McArthur River Field TBU PTD 182-033 NON-CONFIDENTIAL Wednesday, April 16, 2003: I witnessed a No-Flow verification on UNOCAL's Grayling platform well #G-6RD (Short string) in the McArthur River field. Following is a timeline and well status during test. 1030 Well flowing at less than 1 psi & 180 scf, no fluid. 1100 Shut-in well 1220 SITP 1 psi, open well to gas flow gauge, initial flow 500 scf down to <180 1225 Shut-in well @ 0 psi 1255 SITP 0 psi, open well, 200 scf to 0 scf (30 seconds). 1300 Shut-in well 1330 SlTP 0 psi, Open to atmosphere. Flow initially 200 scf decreased 0 scf ( <30 sec.). Note: The gauge used to check flow was incapable of measuring below 180 scf or above 2000 scf. 100-psi gauge used to check tubing pressure. Zero flow indicated by hose in bucket. This well exhibited inability to flow to surface unassisted and I recommend it be granted No-Flow status. I explained to J.C Waski (Platform Lead Operator) that any cleanout, perforating or other stimulation would require another No-Flow test. SUMMARY: I witnessed No-Flow verification on UNOCAL's Grayling platform well #G-6RD (short) in the McArthur River field. NON-CONFIDENTIAL CC; Dwight Johnson (Unocal), J.C. Waski (Grayling platform) Attachment: None No-Flow UNOCAL TBU G-6RD 04-16-03 LG.doc ~KA OIL AND GAS CONSERVATION COH~ISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7= AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 April 22, 2003 Dwight Johnson UNOCAL Field Superintendent PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification TBU Well G-6RD (S), PTD 182-033 Mr. Johnson: On April 16, 2003, our Inspector Lou Grimaldi witnessed a "no-flow test" on UNOCAL's Grayling Platform. The short string (S) of well G-6RD was tested. Mr. Grimaldi arrived on Grayling Platform and found the well isolated from the production system and "flowing" to an atmospheric vessel. Over the course of 3 hours, the well was shut-in, allowed to build up, then opened to flow 3 times. On each occasion, the well quickly died. No-flow was confirmed using a Unocal meter and a "bubble bucket". It has been concluded that the short string (S) of TBU Well G-06RD (182-033) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. The well's performance meets the criteria at 20 AAC 25.265 (b). Therefore the short string (S) is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board Grayling. Sincerely, Sr. Petroleum Engineer TEM:\jjc Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager Thursday, March 23, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Trading Bay Unit Well G-6rd APl No. 50-733-20073-01 10-404 Reperforate G-Zone Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the reperforation of the G2, 3, 4 & 5 benches in well G-6rd. The following intervals were perforated on 12/22/99: Bench Top Bottom Feet G2 9,947 9,972 25 G3 10,014 10,046 32 G4 10,072 10,105 33 G5 10,172 10,227 55 Total: 145 If you have any questions, please contact Ralph Holman at 263-7838. Dan Williamson Drilling Manager STATE OF ALASKA (. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 103' RT above MLLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 1879' FSL, 1385' FEL, Sec. 29, T9N, R13W, SM G-6rd At top of productive interval Top of G Zone at 9950' MD 9. Permit number/approval number 365' FSL, 2418' FWL, Sec. 28, T9N, R13W, SM 82-33/94-333 At effective depth 10. APl number 356' FSL, 2559' FWL, Sec. 28, T9N, R13W, SM 50-733-20073-01 At total depth 11. Field/Pool 358' FSL, 2585' FWL, Sec. 28, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 11000 feet Plugs (measured) 10854 true vertical 9759 feet Effective depth: measured 10854 feet Junk (measured) Fill at 10665 true vertical 9615 feet Casing Length Size Cemented Measured depth True vertical depth Structural 356' 26" Driven 356' 356' Conductor 631' 16" 1450 sx 631' 631' Surface 3036' 13-3/8" 1250 sx 3036' 2879' Intermediate Production 9895' 9-5/8" 2200 sx 9895' 8672' Liner 2491' 7" 600 sx 8509'-11000' 7374'-9763' Perforation depth: measured 9947'-9972', 10014'-10046', 10072'-10105', 10172'-10227', 10368'-10400', 10421'-10441', 10562'-10682' true vertical 8721 '-8745', 8787'-8819', 8844'-8877', 8943'-8998', 9137'-9169', 9190'-9210', 9329'-9447' Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, N-80 from surface to 9928' & 2-7/8", 6.4#, N-80 from 9929' to 10,394' SS: 3-1/2", 9.2#, N-80 from surface to 8402' Packers and SSSV (type and measured depth) Baker "Twin Seal" pkr. at 8352', Otis "BWH" pkr. at 10,306' ~' ~"~ ..... ~'"'~ ~ ii"'" 13. Stimulation or cement squeeze summary Intervals treated (measured) 0 R ! Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure ~ ugmg~ressure Prior to well operation 273 201 209 880 90 Subsequent to operation 344 202 136 900 150 15, A~achments: 16. Status of well classification Copies of Logs and Su~eys run: Daily Repo~ of Well Operations: Oil: X ~as: Suspended: Se~ioe: 17, I hereby ~e~ify that the foregoing is true and correct to the be~t of my knowledge: Signed~~~~~ Title: ~, /Z~/ ~(~, Date~~~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE STATE OF ALASKA ALA~ ~IL AND GAS CONSERVATION COMMI~ ')N REPORT F SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate m Plugging __ Perforate __ Pull tubing __ Alter casing__ Repair well __ Pull tubing m OtherX 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location of well at surface 1879' FSL & 1385' FEL, Sec. 29, T9N, R13W, SM At top of productive interval Top of G Zone @ 9950' MD 365' FSL & 2418' FWL, Sec. 28, T9N, R13W, SM At effective depth 10,870' MD 356' FSL & 2559' FWL, Sec. 28, TgN, R13W, SM At total depth 11,000' 358' FSL & 2585' FWL, Sec. 28, T9N, R13W, SM 5. Type of Well: Development X Exploratory __ Stratigraphio __ Service __ 6. Datum elevation (DF or KB) 103' RT above MLLW 7. Unit or Property name TRADING BAY UNIT 8. Well number G-6RD feet 9. Permit number/approval number 82-33/94-333 10. APl number 50-733-20073-01 11. Field/Pool MCARTHUR RIVER/HEMLOCK 12. Present well condition summary Total depth: measured true vertical 11000' feet Plugs (measured) 10854' 9759' feet Effective depth: measured true vertical 10854' feet Junk (measured) Fill @ 10,677' 9615' feet Casing Structural Conductor Surface Intermediate Production Liner Length 356' 631' 3036' 9895' 2491' Perforation depth: measured Size Cemented Measured depth True verticaldepth 26" Driven 356' 356' 16" 1450 sxs 631' 631' 13-3/8" 1250 sxs 3036' 2879' 9-5~" 2200 sxs 9895' 7" 600 sxs 8509'-11000' 9950'-9970';10030'-10045';10075'-10105';10175'-10195';10370'-10400' 10421'-10440';10562'-10632' 8672' 7374'-9763' true vertical 8727'-8747'; 8806'-8821'; 8521'-8880'; 8949'-8969'; 9141'-9171'; 9190'-9210'; 9329'-9398' Tubing (size, grade, and measured depth) 3.5", 9.2#, N-80, Butt 9928' 2-7/8" 6.4# N-80 Butt 10,394' Packers and SSSV (type and measured depth) 836 Baker Twin ,Seal Triple Bore 51 -A6 pkr 10,319' Otis BWH Pkr _ _ ,, =.. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A KLCL! V Lu jAN 2 4 1995 0il & Gas Cons, Commission 14. Prior to well operation N/A Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation N/A 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X_ 16. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I here ..~e ti~~~e and correct to the best of my knowledge. Signed G. RussetISchmidt Title Drillinq Manager Form 10-404 Rev 06/15/88 Date 1/18/95 SUBMIT IN DUPLICATE '2-753-20075-0t .-=;:,ne Pk]tform ,, on(]uc or - &AST ~0,,,, !~2g - 992g' CROSSOY"ER ~!~ - =,.,, P~ '~.,:. ,,,,,, F ..... r~¢ ..,, .,,.,,. ~' ;~' ~'~°~5/9/82 '~50 10045' PERFS r~' I~HPF,,~ :~375 10105' - = !3HPF. m .~ ~.,n 5/9/82 , i :0681 - :,]70' FIE 9/22/91 '1'~ Bottom ~ 106~1 WLM i i -~- tI~ CE]~}~ PLUO 10955 - 10998 - t 1000' :.~09 - 11000' ?' OD 2B.OO~/f~ N-~O [JbiA ,3 1LE ?BTD: lO&.q' ~: I1000' , ,,,:83 :03'19 10570 10421 10~61 1033 -i0287 -t052g' -i02§' - t0400' -t~1' - t0~2' -tO,gl 3.75" :,.,.. 2.$15" '~' PAC~ '3iis i~H PERE;,,.,'-'=~, 12HPF. !cst r~rf 9/18/91 PERFS n~, 8HPF. !:~ r~rt I.~i]INI; NIPPLE Otis X :~r'~-' ~" tlYES~[ Otis r~-e~ 10562 - t0657 PD~P3 :,~-~, t~od. ~HPF,. 2 ~, Formeo ~'~ I~ Deg, RECEIVED jAN 2 4 1995 Oil & Gas Cons. Commission Anchor~ ~' Oil ~elt Redriited And Commtea 5/19/82 GRAYLING PLATFORM G-6RD (LONG STRING) DAY 1 (12/26/94) 9-5/8" @ 8917' 7" @ 8509'-11,000' TBG TAIL @ 10,394' TRAVEL TO GRAYLING PLATFORM UNLOAD BOAT. DAY 2 (12/27/94) 9-5/8" @ 8917' 7" @ 8509'-11,000' TBG TAIL @ 10,394' RU C.T.U. ON G-6RD LONG. POWER UP RIG #54. DAY 3 (12/28/94) 9-5/8" @ 8917' 7" @ 8509'-11,000' HELD PRE-JOB SAFETY MTG. TEST C.T.U. (SEE C.T.U. BOP CHECKLIST). RIH W/1.75" WASH NOZZLE ON 1.5" COIL TBG. PUMP N2 @ 50. TAG & WASH SCALE 3800'-8000' 9380'-9540'. RUN OUT OF TBG TAIL TAG @ 10,587'. POOH W/CT COUNTER OFF 100'. PU MOTOR & MILL. SHUT DOWN FOR THE NIGHT. DAY 4 (12/29/94) 9-5/8" @ 8917' 7" @ 8509'-11,000' SURFACE TEST MTR (OK). TEST LUB & C.T. TO 3000 PSI W/FIW, OK. RIH W/BHA TAG @ 10,660'. DRILL TO 10,661' MTR KEPT STALLING. POOH. PU 1-7/8" GR ON WlRELINE TAG @ 10,677'. RELEASE C.T.U. 12/29/94 @ 18:00. RECEIVED JAN 2 4 1995 Alaska Oil & Gas Cons. Commission Anchor; APPLI STATE OF ALASKA ~' ~ A OIL AND GAS CONSERVATION C([ SION i'ION FOR SUNDRY PROVALS 1. Type of request: Abandon __ Suspend __ Alter casing__ Repair well Change approved program __ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location of well at surface 1879' FSL & 1385' FEL, Sec. 29, R9N, R13W, SM At top of productive interval TOP OF G ZONE @ 9950' 365' FSL & 2418' FWL, SEC. 28, T9N, R13W, SM At effective depth 10,870' MD 356' FSL & 2,559' FWL, SEC. 28, T9N, R13W, SM At total depth 11,000' 358' FSL & 2585' FWL, Sec. 28, T9N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 11000' 9759' Operations shutdown __ Re-enter suspended well__ Plugging __ Time extension Stimulate Pull tubing _ _ Variance __ Perforate X__ OtherX 5. Type of Well: Development X_ q ECEIVED DEC 1 5 1994 A ska Oil & Gas Cons. Commission Ancho=~;c feet Plugs (measured) NONE feet 6. Datum elevation (DF or KB) 103' RT ABOVE MLLW 7. Unit or Property name TRADING BAY UNIT 8. Well number G-6RD 9. Permit number 10. APl number 50-733-20073-01 11. Field/Pool MCARTHUR FIELD ORIGINAL Effective depth: measured 10854' true vertical 9615' feet feet Junk (measured) FILL @ 10,665' feet Casing Length Structural 356' Conductor 631' Surface 3036' Intermediate Production 9895' Liner 2491' Perforation depth: measured true vertical Size Cemented Measured depth True vertical depth 26" DRIVEN 356' 356' 16' 1450 SXS 631' 631' 13-3/8" 1250 SXS 3036' 2879' 9-5/8' 2200 SXS 9895' 8672' 7' 600 SXS 8509'-11000' 7374-9763' 9950'-9970'; 10030'-10045'; 10075'-10105'; 10175'-10195'; 10370'-10400'; 10421'-10440'; 10562'-10632' 8727'-8747'; 8806'-8821'; 8521'-8880'; 8949'-8.969'; 9141'-9171 '; 9190'-9210'; 9329'-9398' Tubing (size, grade, and measured depth) 3.5", 9.2#, N-80, BLJTT 9928' 2-7/8' 6.4# N-80 BUTT 10,394' Packers and SSSV (type and measured depth) 836 BAKER TWIN SEALTRIPLE BORE 51 -A6 PKR 10,319' OTIS BWH PKR 13. Attachments Description summary of proposal _ _ Detailed operations program_)(_ BOP sketch X_ 4. Estimated date for commencing operation I'15. Statue of well classification as: DECEMBER 19, 1994 / 16. If proposal was verbally approved Oil X_ Gas m Name of approver Date approved Service Suspended 17. I hereby certif~~m~t to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager FOR COMMISSION USE ONLY Date 12/12/94 Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test Mechanical Integrity Test Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form required 10- /-/. o cc.. Original Signed By David W. Johnston Approved Copy Returned .....'/~/~/cbmmissioner/~C~ _ Date /~__/c~/~ ' '?~/' SUBMIT IN TRIPM(~ATE McArthur River Field Grayling C~ Long String Coiled Tubing Clean -Out Procedure Page: I Note: 2) 3) 4) 5) 6) 7) 8) 9) ~Oa) lOb) 11) 12) 13) BOP Shear Test was completed (witnessed by Mitchell Datum) on 12/07/94 Verify tree/CT BOP connections before moving CTU to thc Grayling Platform. (Thread: 3-1/2" 8rd; Flange: 3-1/8" R25 5M psi) Hold safety meeting and discuss procedure w/coiled tubing personnel and production personnel before starting job. Fill out CT pre-job checklist. Review CT's working history before using coil MIRU Dowcll CTU, Nitrogen Unit, pump skid, choke linc, double choke manifold, kill line, flow tank, and return tank. (Allow 2 cla~,~ for rig up time.) Thc Production Foreman and Engineer have allowed taking returns to the separator. NU BOP on G4RD Long String (located in Leg 4). Pressure test BOP, 1-1/2" CT, and all surface lines to 3~000 psi for 10 minutes. Use Nitrogen for pressure test. Complete BOP Inspection MU CT BHA #1 as follows: 1) 2.00" wash nozzle 2) 1-11/16" tandem check valve RIH 1.5" CT w/BI-IA # 1--do not exceed 100 FPM. Begin pumping Nitrogen as soon as CT enters the well. Take returns to the separator. While cleaning out keep well slightly undcrbalanced to aid clean-out. Bottom-hole pressure is 3~100-3~500 psi. Wash fill from 10~665'-10~854'. Use gas lift to assist solids removal. Discuss alternative plans w/office if Nitrogen clean-out is ineffective. If there are no fill returns, attempt to clean-out nsing foam (Surfactants F52.1 & F75N will be available.) If foam does not lffi solids effectively, POOH w/1-11/16" wash nozzle and RIH w/motor and 2-1/8" mill. POOH w/BHA #1 and 1-1/2" CT. RD CTU. ND BOP. Move CTU to G-1RDS Turn well over to production. MWD G6RDLPRO. DOC 12/14/94 McArthur River Field Grayling G-6RD Long String Coiled Tubing Clean -Out Procedure Page: 2 After Coiled Tubing Operations: Hold wireline pre-job safety meeting. 1) 2) 3) 4) 5) 6) RU wireline unit. Test lubricator to 3~000 psi for 10 minutes. Lubricator shall have a pump-in sub. RIH w/Schlumberger strip gun 6 SPF and make tie-in pass w/CCL. Perforate ~:11: 10~700'-10730' Well will be shut-in. POOH w/wireline. RD wireline unit. Turn well over to production. Gas r~ons. ~omm~$sio~ MWD C-6RDLPRO.DOC 12/14/94 .?150-75,3-20075-01 )~¥iina PIotform _~! 2, ~on~uctor 4.,~ Traoi:: !,:v Unit ~4cArt,.::: -':er ~eld (' RKB Dev. 105.0 Ft. bq Head FJna Depth 4-2.85 Mid-Perf De:q'a(ioi 51 geo. · 45- 55t' 16" OD 75.00f/It J-~¢~= s~r^"~ C~ ~ '~1 '"' /1 8509 - 8516' ~e-~ Sl~e g oB 4;.oo///, N- O ~2- 8922' SHOE 10998 - t 10gO' FLOA~HOE B.O.T. I0870 - 1100(7 CENIE~ PLUG 10~1- ~0870' FILL 9/22./91 Tagged Bottom ff 10681 ~ 8509- 11000' ?' OD ~9.001/ft N-80 UNER 10955- 10956' FLCO~ B.O.T. STRING 45- 9928' 5.50(Y' OD 9.20!/ft N-80 TEO LONG STriNG ~ 99LQ-t0355' 2.875" OD 6,40!/tt N-80 l~ L~G ~ 318 - 521' S~ Otis 2875- 2881' GASUFT VAL'E tl, PTA "DSO" C-L~I ,L 4642 - 649' ~UFT ¥&YE t2, PTA"DSO" 5873- 5879' GASUFT VALVE t3, PTA "BSO" 6~ 6905- 6911' ¢.ASUFT VAL~ t4, PTA"DSO" GLli 7625- 7630' ~UFT VALVE t5, PTA"DSO" GLM ~ - 8~79' PACER B~r f~in Seal, fripl~ Bom t~l.tS1 A ~ Pkr 827~- 821]0' ~UFT V~','[ t6, PT,~"DSO" ~ ~25 - ~29' ~¥[ Otis XA 9929 - 9929' CROSSOVER 10285 - 10287,3.75" ~ 2.,31,~" ID SIFE'VE ~s XA 10319- 1032g' P^C~ Oils t~H 10319 - I0329' SF_.,LS 105g;] - t0394' MUll:SHOE ~Js re--en~ guide Oil ~ell Redrilled And Completed 5/19/82 1~/09/94 Section 310.1 Page 2 of 38 15:15 '~'9075623906 DS Anchorase i i i iii iiif~' COILED TUBING OPERATORS MANUAL 2 FEA~B The following components are identified in Figure I aha 2. The BOP commonly found on DoweH 8chlun~berger (DS) coiled tubing units (CTU$) is manufactured ~/Texas 011 Tools (TOT). This is available in a range of .,~izea (bore), pre,ssure ~s and ~ervices (e.g., HzS, Ar(~: or Standard service). · BoP aoo · BUnd Rams The model most commonly used is the 3-In., 10,000-pst Working Pressure, I-I~S aervice Quad BOP. It is this model on which the dlaoran'm and text in this secti= n are based. Stud-Up Flar~ge Top Conneclion~ · Sllp Rams · Pipe Ram8 Pressure Port Blind-Ram Equalizing Valve Manual Lock Handle Side Port (Kill Port) Blind Rams (Ram No. 1) Shear Rams (R~ NO. 2) Slip Rams (Ram No. :3) Pipe Rams (RamNo.4) Pipe. Ram Equalizing Valve Hydraulio Actuator with Ram Position Indicster Bottom F~ Connection Bottom Pin and Collar OonnectJon Figure 1. l'yploal featur~ ~l a quad BOP--front view, · Unocal North America~~ Oil & Gas Division ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region October 6, 1993 Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Ms. Miller: pOhn April 29, 1992 the following intervals were perforated in well G-6RDL at 4 shots per foot, 180° asing: BENCH TOP BOTTOM TOTAL HB4 10,562' 10,632' 70' Ralph P. Holman Engineer Technician RPH/rph RECEIVED OCT 1 2 199~ Alaska 0il & (las Cons. Gommissio~ ;Anchorage ,~ ~. STATE OF ALASKA -" .~. ALASI<-~ '_ AND GAS CONSERVATION COl ,ISSION REPOR 'uF SUNDRY WELL oPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing- AIt-~-r casing__ --~;pair w~l~v~_- Pull tubing----Other__ 2. Name of Operator 15. ype o I1: 6. Datum elevation (DF or KB) Unocal Development X_ RT 103' MSL I Exploratory .... feet~ I 3. Address I Stratigraphic 7. Unit or Property name P.O. Box 196247, Anchorage, Alaska 99519-6247 J Sauce ~ Trading Bay Unit 4. Location of well at surface Leg #2, Conductor #46 1879' N & 1383' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 372' N & 2405' E of SW Cor., Sec. 28, T9N, R13W, SM At effective depth 1525' S & 3942' E of surface location At total depth 362' N & 2571'E of SW Cor., Sec. 28, T9N, R13W, SM 8. Well number G-6RD 9. Permit number/approval number 82 -33/92-093 10. APl number 50-733-20073 -01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical 11,000 feet 9,775 feet Plugs (measured) Effective depth: measured 10,870 true vertical 9,632 feet Junk (measured) feet Casing Length Structural 356' Conductor 631' Surface 3036' Intermediate 9895' Production Liner 2491' Perforation depth: measured Size Cemented Measured depth True vertical depth 26" Driven 356' 356' 16" 1450 sx 631' 631' 13-3/8" 1250 sx 3036' 2879' 9-5/8" 2200 sx 9895' 8672' 7" 600 sx 8509'- 11000' 9950'- 9970',10030'- 10045',10075'- 10105',10175'- 10195', 10370'- 10400',10421'- 10441',10562'- 10632' 7374'- 9763' true vertical 8727'- 8747',8806'- 8821',8851'- 8880', 8949'- 8969',9141'- 9171', 9190'- 9210',9329'- 9398' Tubing (size, grade, and measured depth) 3-1/2",9.2#, N-80@10,280' Packersand SSSV (typeand measured depth) Baker A-5 @ 8430' - 8442', BakerF~ ¢~.,. ,¢l'l~ti~V 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 0CT 1 t 1995 Alaska 0ii & Gas Cons. (;om~tss'to~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 136 150 632 1120 134 -- 946 1320 Tubing Pressure 100 12O 15. Attachments Copies of Logs and Surveys run -- Daily Report of Well Operations _ 16. Status of well classification as: Oil X_ Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. Title ~'tlIlt/t~¢, Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE Unocal North America~'~ Oil & Gas Division ~, Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region October 5, 1993 Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Ms. Miller: On October 19, 1991 the following intervals were perforated in well G-6RDL at 6 shots per foot, 0° phasing: BENCH TOP BOTTOM TOTAL HB1 10,370' 10,400' 30' Sincerely, Ralph P. Holman Engineer Technician RPH/rph .. ,~. , STATE OF ALASKA ALAS_K~ ,_ AND GAS CONSERVATION COt,. ilSSION REPORT OF SUNDRY WELL OPERATIONS 1. Ope~atioRs performed: Operation shutdown Stimulate __ Plugging __ Perforate X_ ' Pull tubing Alter casing__ Repair well Pull tubing __ Other 2. Name of Operator Unocal 3. Address P.O. Box 196247, Anchorage, Alaska 99519-6247 4. Location of well at surface Leg #2, Conductor #46 1879' N & 1383' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 372' N & 2405' E of SW Cor., Sec. 28, T9N, R13W, SM At effective depth 1525' S & 3942' E of surface location At total depth 362' N & 2571'E of SW Cor., Sec. 28, T9N, R13W, SM 5. Type of Well: Development X_ Exploratory __ Strafigraphic __ Service __ 6. Datum elevation (DF or RT 103' MSL 7. Unit or Property name Trading Bay Unit 8. Well number G-6RD 9. Permit number/approval number 82-33/91-325 10. APl number 50 -733-20073 -01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical 11,000 feet 9,775 feet Plugs (measured) Effective depth: measured 10,870 feet true vertical 9,632 feet Junk (measured) Casing Length Size Structural 356' 26" Conductor 631' 16" Surface 3036' 13-3/8" Intermediate 9895' 9-5/8" Production Liner Perforation depth: measured Cemented Measured depth True vertical depth Driven 356' 356' 1450 sx 631' 631' 1250 sx 3036' 2879' 2200 sx 9895' 8672' 2491' 7" 600 sx 8509'- 11000' 9950'- 9970',10030'- 10045',10075'- 10105',10175'- 10195', 10370'- 10400',10421'- 10441' 7374'- 9763' true vertical 8727' - 8747', 8806' - 8821', 8851' - 8880', 8949' - 8969', 9141' - 9171', 9190' - 9210' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 10,280' Packers and SSSV (type and measured depth) Baker A-5 @ 8430' - 8442', Baker F-1 @ 10,292', Otis SSSV 13. Stimulation or cement squeeze summary RE~..~iVEi'~ Intervals treated (measured) Treatment description including volumes used and final pressure 0CT 1 2 199 Alaska 0ii & Gas Cons. C0mm'~ssio~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 188 -'~'~ 146 892 1210 150 48 1079 1320 Tubing Pressure 120 140 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas _ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title 10_,,.{ ~/-.~ ' Signed Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOFY: (907) 276-7542 July 14, 1993 Mr. G. Russell Schmidt Ddlling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Tradlng Bay Unit, AOGCC Forms 10-403 ahd 10-404 Dear Mr. Schmidt, In' conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. To be in compliance with AS' 20 AAC 25.280(d) of the Regulations, the Form 10,404 is required to be [~ied within 30 days following completion of work. In previous telephone conversat~ conceming the subject, it had been._explained to me that either ARCO or Marathon had been th~ ~al~(~ perator on the majority of the work proposed; hoWeye[, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Applicaflor~of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problemin the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application. on file can'be marked accordingly. . Sincerely, Statistical Technician printed on recy~:led paper b y ~'i Well No. D'4 D-5RD D-26 D-27 D-40 D-42 D-46 Permit No. 82-41 80-65 74-9 75-24 82-83 83-53 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22,91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Description Perforate 2-91 Perforate 5-91 Workove~ 4291 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By_ G. Bush G. Bush G. Bush G. Bush G. Bush' G. Bush G. Bush G. Bush G. Bush , G. Bush G-5 G-6 67-71 3/15-91, 91-086' 10-30-91, 91-325 4-21-92, 92-093 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this wel~ · Perf. 10-19-91 Perf 4-92 - G. Bush -. .. G. Bush G. Bush G-17 G-19 G-21 G-27 78-3 69-17 72-42 · - G-31 69-72 67-65 K-2RD 78-38 11-1-91, 912331 11-10-92, 92-238 4-21i92, .92-094 6-17-93, 93-154 4-21'92, 92-95 i-6-93, 92-203 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 K-3 80-144 2-9-90, 90-081 K-9 68-38 11-14-89, 9-987 Perforate G. Bush Temp. log 10-15-92 G. Bush. Perf4-92 Coil tubingcleanout _ Perforate Convert to inj. . -. _. -.. · .... ,. _Gib, Bush_.'' '". R S chmidt Production profile Perforate 2/90 G. Bush R. Roberts Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 R. Roberts G. Bush G. Bush Perforate 2/90 R. Roberts Repair well, p. tubing, stimulate, perforate R. Roberts Unocal North American Oil & Gas Division ~'~ Unocal Corporation [, D.C. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region DOCUMENT TRANSMITTAL November 13, 1992 TO' Larry Grant FROM: Kirk Kiloh LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS TRADING BAY UNIT G-6RI~ ~uelines and 1 sepia Perforating Record PLEASE ACKNOWLEDGE RECEIVI' BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU DATED: Gas Cons. 0om~io.q_n STATE OF ALASKA ,~ , ALASKA OIL AND GAS CONSERVATION COMMISSION . AP, PLICA[3N FOR SUNDRY AP{' IOVAL ;R I Type of request: Abandon Suspend Operatlom shutdown m Re-enter suspended well__ "~ Alter casing t Repak well __ Plugging t Time extension m Stimulate __ Change approved program __ Pull tubing m Variance __ Perforate X_ Other__ 2. Name of Operator Union Oil Company of Califomia (UNOCAL) 3. Address P.O. Box 196~47, Anchorage, Alaska 99619-6247 5. Type of Well: Explorato~/ . Localion of well at stxface Leg 2, Cond. 76, 1879'N & 1383'W of SE Cor. Sec. 29,T9N, R13W, SM At top of producUve Interval 372'N & 2405'E of SW Cor., Sec. 28, TDN, R13W, SM At effective depth 1525'S & 3942'E of surface location At total depth 362'N & 2571 'E of SW Cor., Sec. 28, TDN, R13W, SM RECEIVED APR 1 6 1992 Alaska 0il & Gas Cons. Gom~s Present well condition summary Total depth: measured true vertical 11,0(X) feet 9,775 feet ~,cbqrage Plugs (measured) 6. Datum elevation (DF or KB) RT 103' MSL 7. Unit or Property name Trading Bay Unit 8. Well number G-6RD 9. Permit number 82-33 10. APl number 50 -733 -20073-01 ,,~0kField/Pool ~'~'t~cArthur River Field/Hemlock feet Effective depth: measured true vertical 10,870 feet Junk(measured) 9,632 feet Caalng Structural conductor Surface Intermediate Production Uner Perforation depth: Length Size Cemented Measured depth 356' 26" Driven 356' 631' 16" . 1450 sx 631' 3036' 13-3/8" 1250 sx 3036' 9895' 9-5/8' 2200 sx 9895' 2491' 7" 600 sx 8509' - 11,000' measured 9950' - 9970'; 10,030' - 10,045'; 10,075' - 10,105'; 10,175' - 10,195'; 10,370'- 10,400'; 10,421'- 10,441' true vertical 8727' - 8747'; 8806' - 8821'; 8851 - 8880'; 8949' - 8969';9141' - 9171' 2879' 8672' 7~4'-97~' Tubirlg(size, grade, and measured depth) 3-1/2",9.2#,"-~0@10,2~0' I::)~-~-I"~r~ Packers and SSSV (type and measured depth) Baker A-5 8430' - 8442'; Baker F-1 @ 10,292'; Otis SSSV @ 293' 13. Attachments Description summary of proposal __ Detailed operations programX__ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: April, 1992 16. If proposal was verbally approved Oil X_ Gas ~ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of bl~proval: Notify Commission so representaUve may witness ' Plug Integrity ~ BOP Test Location clearance Mechanical Integrity Test~ S'"~bsequent form required 1"'~- Date IApproval No. Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C SNIITH Commissioner SUBMIT IN TRIPLICATE April 3, 1992 ~ra¥1inq, Well G-$RD perforatin~ procedure 1. Hold safety meeting. 2. RU electric line unit. 3. Pressure test lubricator to 2500 psi for five minutes. 4. Shut down all welding and radio transmissions. 5. RIH and perforate intervals as instructed by Unocal (When gun is 200' below surface, welding and radio transmissions may resume. ) 6. POOH. (When gun is 200' below surface, shut down all welding and radio transmissions. ) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH MEASURED TRUE VERTICAL TOTAL FEET HB4 10,562'-10,662' 9332'-9431' 100' TOTAL 100' RE' EIV D APR 1 6 1992 Alaska Oil & Gas Cons. Com~'tss'ton Anchorage 16" 75~ J-55 0 631' / 1# J-55 3036' RKB - 0.00' mOH~S 7" 29# N-80 TOL ~ 8509' 47# N-80 · 8922' 7" L ~ 11000" TUBING DETAIL: LS: 3-1/2", 9.2#, N-80 BUTTRESS (SP CL) 2-7/8", 6.4#, N-80 BUTTRESS (SP CL) SS: 3-1/2", 9.2#, N-80, BUTTRESS (SP CL) ~, SHORT STRING A) ohs 3-1/2" sssv · 316' B) PTA 'OSO" GLM'S GLM ~tl · 2813' O..M d12 · 45117' GLM #3 · 6025' Gad t4 · 6700' O.M #5 · 7254' GUa ~6 · 7809' GUa #7 · 829? C) OTIS 3-1/2" 'XA# SLE:L'V[ · 831:3' D) WER DI2AL. PKR · 8:352. L') OhS 2-7/8' 'XN" NFPLr · 640~ 2-7/8' .£-DrmY ~uec · 64~ "G" ZONE: G-2 9947'- 9972' G-3 10014'- 10046' LONG STRING 1) OTIS 3-1/2" SSSV · 316. 2) mA '1:)SC)' GUtS GLM ~1 · 2874' ~ #2 · 4764' g.M #3 · 5872. GUd 14 · 6904° GLId #5 · 762:3* GUd IS · 027:3* ,3) OTiS ~ 1/2'"' "XA" ~ · e320' s) 3-1/2- x 2-7/6.'. X-OVER · 0926' · 6)'2-7/8' sTEB. BLAST JTS (3.5 oo) F/99291 TO 10283' 7) ons 2-7/e- -x~- su~'vE · 6) 2-7/e' sm scm' LOC~Tm ASSY F'/ 10316. TO 103SB' 9) OhS 2-7/8" "x" NFPtZ · lO3ae to) 2-7/a" R£-r. mw~ OtaD£ · 4#e,P 1~) ohs "BWH" PERU PKR · RECEIVED 11 G-4 10072'- 10105' G-5 10172'- 10227' ' HEMLOCK ZONE: APR 1 6 1992 Alaska Oil & Gas Cons. Comm'tss'to~ Anchorage HB-1 10368'- 10400' FRAC W/ 32,000# 20-40 MESH CARBOLITE HB-2 10421'- 10441' HB-4 10562'- 10682' FRAC W/ 20,300# 20-40 MESH CARBOLITE WELL TBUS G-6RD COMPLETION(6-4-91) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 8-7-9 1 APPLICATION FOR SUNDRY APPROVALS0 R i 6 1. Type of Request: Abandon m Suspend __ Operation shutdown __ Re-enter suspended well __ Alter Casing __ Repair well __ Plugging ~ Time extension __ ~,Stimulate ~ Change approved program __ Pull tubing ~ Variance __ Perforate A Other __ 2. Name of Operator / Type of Well: 6. Datum elevation (DF or KB) Union Oil Company.::of California (Unocal) 5. Development~..~_ RT 103' MSL Exploratory __ 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 190247, Anchorage, AK 99519-02 7 Service__ Trading Bay Unit 4. Location of well at sudace Cond. elTO, Leg 1879' N & 1383' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 372' N &'2405' E of SW Cor., Sec. 28, TgN, R13W, SM At effective depth 1525' S & 3942' E of Surface Location At total depth 362' N & 2571' :E of SW Cor., Sec. 28, TgN, R13W, SM 12. Present well condition summary Total depth: meas'ured 11,000 feet Plugs (measured) true vertical 9,775 feet 8. Well number 6-CRD 9. Permit number 82-33 10. APl number 50--733-20073-01 11. Field/Pool McAr thur River/Hemlock RECEIV£D Effective depth: · measured 10,870 feet Junk(measured) true vertical 9,63 2 feet Casing Length Size Cemented Structural 356 ' 26" Driven Conductor 631' 16" 1,450 sx 0CT 2 § 199t Alaska 011 & 6as Cons. Commissio~ Measured del~l~chorage True vertical depth 356' 356' 631' 631' Sudace 37;036:t 13 3/8" 1,250 sx 3,036' 2,879' Intermediate 9,895' 9 5/8" 2,200 sx 9,895' 8,672' Production Liner Perforation depth: 2,491' 7" 600 sx 8509'-11,000' 7374'-9763' measured 9950'-9970'; 10,030'-10,045'; 10,075'-10,105'; 10,175'-10,195'; 10,370'-10,400'; 10,421'-10,441' true vertical 8727'-8747'; 8806'-8821'; 8851'-8880'; 8949'-8969' ;9141'-9171' feet Tubing (size, grade, and measured depth) 3 1/2", 9.21~, N-80 @ 10,280' Packers and SSSV (type and measured depth) Baker A-5 8430'-8442', Baker F-1 @10,292' , Otis SSSV 13. Attachments Description summary of proposal __ Detailed operations program .2L BOP sketch __ 14. Estimated date for commencing operation October 19, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knOwledge. Signed ~-'~o.,,.,~ ~.~. (~,..,,~'~ Title ~z.c~,'~.~ ~:~-\%, %c. Date U::,ozt-~ ('~ (~ ' FOR COMMISSION USE ONLY "" Conditions of',al~pro~ Notify Commission so representative may witness IAppr°val N °c~',/.--,~,25 "--- Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- z~ Approved Copy / Returned /1- ~-~!1 ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C RMITH Commissioner Date J 0- 50 - q I Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE October 17, 1991 G-6RD Perforating Procedure 1. RU slick line, run gauge and tag bottom. 2. Hold saftey meeting. 3. RU electric line unit. 4. Pressure test lubricator to 2,500 psi for five minutes. o . Shut down all welding and radio transmissions. RIH and perforate intervals as instructed by Unocal representative (welding & radio transmissions may resume when gun is 200' below surface). 7. POOH (shut down all welding and radio transmissions). 8. Repeat steps 5, 6 & 7 as needed to perforate in the following intervals: Hemlock Bench Cf1 Measured: 10,370'-10,400' RECEIVED 00T 5 t991 Alaska 0il & 6as 0ohs. Anchorage ALAf STATE OF ALASKA .~ ,OILAND GAS CONSERVATION COMMIS( REPORT OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown __ Stimulate _.~ Plugging __ Perforate __ Pull tubing __x Alter casing w Repair welt __ Pull tubing __ Other _~x . 3. Address .P.O. Box 190247~ Anch., 4. Location of well at surface Leg # 2, 1879' FSL & 1385' FEL, At top of productive interval 365' FSL & 2418' FWL, At effective depth 356' FSL & 2559' FWL, '"'12. Present well condition summary Name of Opera{q~.NOCAL ) 5. Type of Well: Development ..~ ~on Oil Company 9~ California Exploratory__ Stratigraphic __ AK, 99519 Service __ Conductor #46 Sec 29, T9N, R13W, SM Sec 28, T9N, R13W, SM @ 9950' ! Sec 28, T9N, R13W, SM @ 10854'i Sec 28, T9N, R13W, SM @ ll000'M£ 6. Datumelevation(DForKB) 103' RT above MLL~eet ZUnitorPropertyname TRADING BAY UNIT 8. Wellnumber G-6RD 9. Permit numbedal3proval number 82-33/90-755 .~i~APl hum 50-- ~3-20073-01 ,,,,, FW~/~°~ONE/Wost Forela Total depth: measured 11,000 ' feet Plugs (measured) true vertical 9,759' feet Effective depth : measured 10,854' feet Junk(measured) true vertical 9,616 ' feet Casing Length Size Cemented Structural 3 56 ' 26" DRIVEN Conductor 631 ' 16" 1450 SXS Surface 3036 ' 13-3/8" 1250 SXS Intermediate 9895' 9-5/8" 2200 SXS Production 2491' 7" 600 SXS Liner Perforation depth: measured Measureddepth ~ueve~icaldepth 356' 356' 631' 631' 3036' 2879' 9895' (WINDOW @ 8917') 8672' 8509'-11000' 7374'-9763' truevertical See attached perforation record Tubing (size. grade, andmeasureddepth~-l/2" 9.2# N-80 Butt; SS @ 8402' LS @ 10394' Baker Twin Seal dual @ 8378'; Otis BWH single @ 10290' Packers and SSSV (type and measured depth) Otis SSSV SS @ 316' LS @ 317' '13. Stimulation or cement squeeze summary Intervals treated (measured) 14. See attached history Treatment description including volumes used and final pressure SS: LS: Prior to well operation SS: Subsequent to operation LS: , , 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ Representative Daily Average Production or Injection Data 2~l~bl ~cf Water&l~l Cg_s~ 89 268 338 1375(GL) 391 152 125 l195(GL) 210 260 774 1195 (GL) 16. Status of well classification as: Oil ~ Gas_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. AUG 2 9 1991 Naslm Oil & Gas Cons. CommiSsien Tub/~ressure 160 120 150 Suspended Service Gary~ Bush Signed __~,~Q~ ~, ~:::~~ Form 10-404 Rev 06/~t5'~88 (,_,)' Regional Drilling Manager Title Date SUBMIT IN DUPLICATE PERFORATION RECORD TBUS G-6RD 6/5/91 "G" ZONE 9947'- 9972' MD 10014'- 10045' MD 10072'- 10105' MD 10172'- 10227' MD 8700'- 8717' TVD 8731'- 8739' TVD 8772'- 8801' TVD 8822'- 8830' TVD OPEN-PROD OPEN-PROD OPEN-PROD OPEN-PROD HEMLOCK ZONE 10368'- 10400' MD 9737'- 9739' TVD OPEN-PROD FRAC'D WITH 32,000# 20-40 CARBOLITE 10421'- 10441' MD 9678'- 9681' TVD OPEN-PROD 10580'- 10682' MD 9723'- 9725' TVD OPEN-PROD FRAC'D WITH 20,300~ 20-40 CARBOLITE RECEIVED AU G ~ 9 1991 Alaska Oil & Gas Cons. i:;omm'~ss~e~ Anchorage GRAYLING PLATFORM G-6RD WOP~KOVER WELL HISTORY DATE MW ETD 04/26/91 10870' 04/27/91 10870' 04/28/91 10870' RECEIVED PAGE 1 COMMENTS COMMENCE OPERATIONS ON TBUS G-6RD WORKOVER AT 0000 HOURS ON 4/26/91~ RIG UP TO BULLHEAD 3% KCL/FIW INTO THE LONG STRING. BULLHEADED 110 BBL OF BRINE AT 2.5 BPM WITH 1700 PSI. SHUT-IN PRESSURE = 400 PSI. BLED BACK 15 BBLS TO THE TRIP TANK AND LONG STRING QUIT FLOWING. RIGGED UP WIRELINE ON LONG STRING. RIH WITH 2.7" OD TUBING CUTTER TO 10268' TM (10' BELOW "XA" ABOVE PERM PKR) AND CUT TUBING. PUMPED BRINE DOWN THE LONG STRING TAKING RETURNS UP THE SHORT STRING UNTIL RETURNS WERE CLEAN (214 BBLS) TO KILL THE G-ZONE. BOTH TUBING STRINGS ON A SLIGHT VACUUM. RIH WITH 2.7" OD TUBING CUTTER TO 8375' TM (10' BELOW GLM ABOVE DUAL PKR) AND CUT THE LONG STRING. CIRCULATED BRINE DOWN THE LONG STRING TAKING RETURNS ON THE ANNULUS UNTIL THE RETURN FLUID WAS CLEAN (550 BBLS). MONITOR WELL- EVERYTHING ON A SLIGHT VACUUM. RIGGED UP WIRELINE ON SHORT STRING. RIH WITH 2.25" OD TUBING CUTTER TO 8427' TM (15' BELOW XA ABOVE DUAL PKR) AND CUT TUBING. MONITOR WELL- LOSING 20 BBL/HR. INSTALLED BPV'S AND REMOVED DUAL PRODUCTION TREE. CONTINUED REMOVING PRODUCTION TREE. NIPPLE UP BOPE. INSTALLED 3-1/2" X 2-7/8" DUAL BLOCKS IN TOP PIPE RAMS. INSTALLED 3-1/2" X 3-1/2" DUAL BLOCKS IN BOTTOM PIPE RAMS. MADE UP KELLY AND SET BACK SAME. TESTED BOPE PER UNOCAL SPECIFICATIONS AS FOLLOWS: RAM PREVENTERS, CHOKE MANIFOLD VALVES, AND SAFETY VALVES TO 300 PSI (LOW) AND 3000 PSI (HIGH); ANNULAR PREVENTER TO 300 PSI (LOW) AND 2500 PSI (HIGH). INSTALLED NEW RACKING BOARD AND LEVELED DERRICK. MIX 40 BBL 280 VIS HEC PILL AND PUMPED'DOWNLONG STRING TO CONTROL FLUID LOSS. RIGGED TO PULL DUAL COMPLETION. PULLED HANGERS TO FLOOR AND REMOVED SAMEAT 2400 HOD-RS. PULLED OUT OF HOLE LAYING DOWN DUAL GAS LIFT PRODUCTION COMPLETION. LAID DOWN DUAL 3-1/2" TO THE BALL VALVES. RIGGED TO PULL DUAL 3-1/2" X 2-7/8". CONTINUED PULLING OUT LAYING DOWN COMPLETION. TUBING LOOKS GOOD, THREADS ARE TIGHT AND GALLED, LITTLE SCALE. GRAYLING PLATFORM G-6RD WORKOVER WELL HISTORY DATE 04/29/91 04/30/91 05/01/91 ETD 10870' 10870' 10870' PAGE 2 COMMENTS CONTINUED LAYING DOWN 3-1/2" X 2- 7/8" DUAL GAS LIFT COMPLETION. RECOVERED 8386' OF LS AND 8428' OF SS (LS CUT OFF=9.2', SS CUT OFF=15.3'). LONG STRING TOP WAS FLARED TO 4.25" OD. RIGGED DOWN DUAL HANDLING EQUIPMENT. CLEAR AND CLEAN RIG FLOOR. HELD AN "ABANDON PLATFORM" DRILL WITH ALL PLATFORM PERSONNEL. CHANGED UPPER PIPE RAMS TO 5" BLOCKS AND LOWER PIPE RAMS TO 3-1/2" BLOCKS. PRESSURE TESTED ALL RAM TYPE PREVENTERS TO 300 PSI (LOW) AND 3000 PSI (HIGH). SKID CROWN TO CENTER UP ON WELL. MADE UP 2" TUBING TAILAND RAN IN HOLE PICKING UP 5", 19.5#, X-95 DRILL PIPE. CONTINUED RUNNING IN HOLE WITH CLEAN OUT ASSEMBLY PICKING UP 5" DRILL PIPE. WASHED DOWN FROM 8367' DPM TO 8455' DPM. TAGGED PACKER AT 8455' DPM. CIRCULATED BOTTOMS UP AT 16 BPM. MONITOR WELL-STATIC. TRIP FOR FISHING ASSEMBLY. TOP OF LS FISH AT 8400' DPM. TOP OF SS FISH AT 8439' DPM. MADE UP OVERSHOT WITH BASKET GRAPPLE AND RAN IN HOLE. CONTINUED RUNNING IN HOLE. TAGGED LS FISH AT 8398' DPM. DRESSED TOP OF STUB. ENGAGED FISH. JARRED ON FISH WITH 75K OVERPULL. JARRED AN ADDITIONAL HOURAT 165K OVERPULLAND FISH CAME FREE. CIRCULATED WELL CLEAN. TRIP TO CHECK RECOVERY. RECOVERED 62.83' OF FISH INCLUDING 8.55' OF LONG STRING MANDREL FROM THE DUAL PACKER. MANDREL PARTED AT THE LS LOCK RING JUST BELOW THE SHEAR RING. MADE UP A 3-3/8" OD STINGER (5') TO SLIDE INSIDE THE LS MANDREL BORE OF THE DUAL PACKER. MADE UP STINGER ON ONE JOINT OF 3- 1/2" TUBING AND RAN IN HOLE ON 5" DRILL PIPE. STABBED INTO THE LS MANDREL BORE. RIGGED UP WIRELINE AND RAN IN WITH A 2.75" OD TUBING CUTTER. CUT LONG STRING BELOW THE DUAL PACKER AT 8494' WLM (14' BELOW). RIGGED DOWN WIRELINE. TRIP FOR FISHING ASSEMBLY. RE'¢EIVED AUi3 9 Alas. l~a.Oil & Gas Cons. Commissien Anchorage GRAYLING PLATFOR~ G-6RD WORKOVER WELL HISTORY DATE MW 05/02/91 05/03/91 05/04/91 RECEIVED AU 2 9 t991 Alaska Oil & Gas Cons. commission :Anchorage ETD 10870' 10870' 10870' PAGE 3 COMMENTS MADE UP 7-5/8" OD X 6-15/16" ID OVERSHOT DRESSED WITH A HOLLOW MILL CONTROL AND 2-7/8" GRAPPLE. RAN IN HOLE AND TAGGED THE TOP OF FISH AT 8440' DPM. MILLED OVER THE TOP AND SWALLOWED 7' OF 2-7/8" TUBING (SHORT STRING). ATTEMPTED TO MOVE FISH-NO GOOD. WORKED FISH WITH l15K OVERPULL (DID NOT TRIP JARS) AND SOMETHING CAME LOOSE. CIRCULATED BOTTOMS UP AND TRIPPED TO CHECK TOOLS. RECOVERED UPPER HALF OF THE PACKER BODY AND THE SHORT STRING MANDREL. DOWN FOR 3-1/2" HOURS TO REPAIR THE HYDRO-MATIC TANK AND AN ADDITIONAL 2 HOURS WAITING ON A SPEAR EXTENSION TO BE BUILT. MADE UP A SPEAR WITH A 3" GRAPPLE AND RAN IN HOLE TO THE TOP OF FISH AT 8463' DPM. WORK GRAPPLE DOWN TO 8466' DPM. TRIPPED TO CHECK RECOVERY- NONE. RUN IN HOLE WITH SAME SPEAR AT 2400 HOURS. FINISHED TRIP IN HOLE WITH SPEAR AND TAGGED FISH AT 8463' DPM. TRIPPED TO CHECK RECOVERY-NONE. CHANGED GRAPPLE ON SPEAR TO 3-1/2" OD AND RAN IN HOLE. ENGAGED FISH AT 8463' DPM. PULLED OUT TO CHECK RECOVERY- HAD SOME DRAG OFF BOTTOM. RECOVERED REMAINDER OF DUAL PACKER BODY, SHORT STRING TAIL, AND 12.63' OF LONG STRING TO THE CUT. MADE UP OVERSHOT WITH 3-1/2" GRAPPLE AND HOLLOW MILL. RAN IN AND TAGGED FISH AT 8480' DPM. MILLED OVER TOP OF FISH AND LATCHED SAME. CIRCULATED BOTTOMS UP AND PULLED OUT OF HOLE. RECOVERED 1796.16' OF 3-1/2" TUBING AND BLAST JOINTS. LAYING DOWN 6-1/2" OD COLLARS AT 2400 HOURS. FINISHEDLAYING DOWN 6-1/2" OD DRILL COLLARS. PICKED UP 4-3/4" OD DRILL COLLARS. MADE UP 5-3/4" OD OVERSHOT WITH 3-1/2" GRAPPLE AND HOLLOW MILL. RAN IN PICKING UP 1575' OF 3-1/2" DRILL PIPE. CROSSED OVER TO 5" DRILL PIPE AND CONTINUED IN TO TOP OF FISH AT 10276' DPM. MILLED OVER FISH TO 10283' DPM. WORKED FISH LOOSE AND CIRCULATED WELL CLEAN. TRIP TO CHECK RECOVERY-RECOVERED BALANCE OF LONG STRING. MADE UP 5- 7/8" X 4-7/8" BURNOVER SHOE ANDRAN IN HOLE. TAGGED PACKER AT 10303' DPM. MILLED OVER PACKER TO 10307' DPM AND PACKER FELL FREE. CHASED PACKER TO 10330' DPM AT 2400 HOURS. GRAYLING PLATFORM G-6RD WORKOVER WELL HISTORY DATE 05/05/91 05/06/91 05/07/91 ETD 10870' 10870' 10870' PAGE 4 COMMENTS TRIP FOR SPEAR. MADE UP SPEAR ASSEMBLY WITH 4" OD GRAPPLE. RAN IN HOLE AND TAGGED PACKER BODY AT 10330' DPM. CHASED PACKER TO 10559' DPM. SET DOWN ON PACKER WITH 25K. TRIP TO CHECK RECOVERY-RECOVERED PACKER BODY. TEST BOPE TO UNOCAL SPECIFICATIONS. MADE UP 8-1/2" BIT AND 9-5/8" CASING SCRAPER. RAN AND IN TAGGED THE TOP OF THE 7" LINER AT 8517' DPM. TRIP FOR 6" CLEAN OUT ASSEMBLY. RAN IN HOLE WITH 6" BIT AT 2400 HOURS. CONTINUED IN WITH 6" CLEAN OUT ASSEMBLY. TAGGED FILL AT 10554' DPM. CLEANED OUT FILL TO 10870' DPM ETD. TIGHT SPOT FROM 10626' TO 10628' DPM-WORKED THRU TWICE TO FREE UP. CIRCULATED WELL CLEAN. PULLED 3 STANDS WITH INCREASING DRAG. WENT BACK TO BOTTOM AND PUMPED A HIGH VIS SWEEP. PULLED OUT OF HOLE. MADE UP A 7" CASING SCRAPER WITH A 6" BIT. RAN IN HOLE TO 10866' DPM. TRIP FOR SQUEEZE PACKER. SLIPPED AND CUT DRILLING LINE ON TRIP OUT OF HOLE. COMPLETED TRIP OUT OF HOLE. MADE UP A 7" RTTS PACKER AND RAN IN HOLE. SET PACKER IN THE 7" LINER AT 9900' DPM. PRESSURE TESTED THE CASING AND LINER LAP TO 3000 PSI. PRESSURE BLED DOWN 140 PSI IN 30 MINUTES. TRIP FOR CEMENT RETAINER. MADE UP A HOWCO 7" EZSV CEMENTER RETAINER AND RAN IN HOLE ON DRILLPIPE. SET RETAINER OF 10742' DPM. UNSTABBED FROM RETAINER AND CIRCULATED WELL WHILE STRINGING IN POLY-BREAK"S". MIXED 1 DRUM OF DIRT MAGNET IN 100 BARRELS OF FIW. PUMPED DIRT MAGNET SWEEP FOLLOWED BY CLEAN 3% KCL/FIW UNTIL RETURNS WERE CLEAR. CLEANED PITS. CIRCULATED AND FILTER FLUID. Alaska Oil & I~as Cons. Cornmissien Anchorage GRAYLING PLATFORM G-GRD WORKOVER ~ HISTORY DATE 05/08/91 05/09/91 ETD 10870' 10870' PAGE 5 COMMENTS CONTINUED TO CIRCULATE AND FILTER FLUID TO LESS THAN 50 NTU'S. PULLED OUT OF HOLE WITH EZSV RUNNING TOOL. MADE UP HOWCO TEST HEAD ASSEMBLYAND LAID DOWN SAME. MADE UP TCP GUN ASSEMBLY ANDRAN IN HOLE ON 5" DRILL PIPE. FILLED PIPE WITH BRINE FOR AN 800 PSI DRAWDOWN. RIGGED UP SCHLUMBERGER FOR TIE IN RUN. RAN IN WITH GR/CCL. ATTEMPTED TO TIE IN GUNS. HAD A LOT OF HOT SPOTS ON GAMMA RAY FROM WATERFLOOD. HAD TWO SPOTS THAT LOOKED LIKE THE RA TAG. MOVED DRILL PIPE 10' AND RELOGGED TO LOCATED RA TAG. WIRELINE MEASUREMENTS WERE OFF AND LOGGING TOOL SHEARED THE BAR PRESSURE VENT SUB. LOST UNDERBALANCE AND STUCK WIRELINE. REVERSED ONE COMPLETE CIRCULATION WHILE WORKING STUCK WIRELINE. WORKED LINE WITH 6000# OVERPULL AND TOOLS CAME FREE. PULLED OUT OF HOLE AND RIGGED DOWN WIRELINE. TRIP PERFORATING ASSEMBLY TO REDRESS BAR PRESSURE VENT SUB. CONTINUED TO PULL OUT OF HOLE WITH PERFORATING ASSEMBLY. REPLACED BAR PRESSURE VENT SUB AND FIRING HEAD. RAN TCP GUN ASSEMBLY IN HOLE FILLING PIPE WITH BRINE FOR AN 800 PSI DRAWDOWN. MADE UP TEST HEAD AND SPACED OUT BY DRILL PIPE MEASUREMENTS. RIGGED UP WIRELINE. RAN GR/CCL TO CORRELATE GUNS WITH SCHLUMBERGER GR/DIL LOG DATED 4/14/82. SET PACKER AND RAN CONFIRMATION LOG. RIGGED DOWN WIRELINE. LOADED DROP BAR AND RIGGED UP SHOT DETECTION EQUIPMENT. DROPPED BAR AND FIRED GUNS AT 1245 HOURS PERFORATING HEMLOCK BENCH 4 FROM 10580' TO 10682' DIL WITH 4- 5/8", 8 HPF CARRIERS WITH 25 GRAM DEEP PENETRATING CHARGES. PULLED PACKER LOOSE AND REVERSED TWO DRILL PIPE VOLUMES. CIRCULATED AND FILTERED FLUID THE LONG WAY. CHECKED FOR FLOW-STATIC. PULLED OUT AND LAID DOWN TCP GUN ASSEMBLY-ALL SHOT FIRED. MADE UP A MULE SHOE ON 5" DRILL PIPE AND RAN IN HOLE. RECEIVED AU S 2 9 1991 .Oil & Gas Cons. Commi~|en '.Anchorage GRAYLING PLATFORM G-6RD WORKOVER WELL HISTORY DATE 05/10/91 05/11/91 ETD 10870' 10870' PAGE 6 COM~{ENTS CONTINUED TO RUN IN WITH MULE SHOE AND TAGGED FILL AT 10733' DPM. WASHED DOWN TO 10738' DPM. CIRCULATED AND FILTERED FLUID. TRIP FOR HOWCO 7" RETRIEVABLE BRIDGE. PLUG. RAN IN AND SET RBP AT 10475' DPM. PULLED TO 9880' DPM AND DISPLACED 20 BBL OF CACO3 LCM PILL TO THE END OF THE DRILL PIPE. SHUT WELL IN AND BRADEN HEAD SQUEEZE LCM PILL INTO THE G-ZONE, HB-1AND HB-2. PRESSURE BUILT TO 2500 PSI WITH 8 BBL SQUEEZED. ALLOWED PRESSURE TO BLEED AND RESQUEEZED 5 TIMES. LEFT WELL SHUTIN FOR 30 MINUTES AND PRESSURE BLED TO 1800 PSI. PUMPED BACK UP TO 2500 PSI WITH 1.8 BBL. LEFT WELL SHUT IN FOR 30 MINUTES AND PRESSURE BLED TO 1900 PSI. RAN IN TO 10470' DPM AND CIRCULATED OUT EXCESS LCM PILL. LATCHED RBP AND PULLED SAME LOOSE WITH 20K OVERPULL. PULLED UP TO 9808' DPM AND RESET RBP TO ISOLATE ALL PERFORATIONS. PULLED TO 9714' DPM AND MADE UP HANGER TEST PLUG WITH IBOP VALVE ON TOP. LANDED HANGER WITH OEDP AT 9756' DPM AND RAN IN LOCKDOWN PINS. ATTEMPTED TO TEST ANNULUS-PLUG WOULD NOT TEST. CHECKED SEALS AND RETEST-NO GOOD. CLOSED BLIND RAMS AND BEGAN REPLACEMENT OF DRAWWORKS BRAKE FLANGES WHILE WAITING ON FRAC EQUIPMENT FROM THE DOLLY VARDEN. CONTINUED TO WORK ON BRAKE FLANGE REPLACEMENT EQUIPMENT ON RIG #54. CHECKED DRUM BEARING. REMOVED DRUM FROM DRAW-WORKS. REMOVED HIGH AND LOW CLUTCH/SPROCKETS. REMOVED OLD BRAKE FLANGES. INSTALLED NEW BRAKE FLANGES. REPLACED CLUTCH/SPROCKETS. INSTALLED DRUM. LEFT OUT ROTARY DRIVE AND ROTARY CLUTCH-SYSTEM IS NOT OPERABLE. RECEIVED .Oil,& Gas Cons. Commissien 'Anchorage: GRAYLING PLATFORM G-6RD WORKOVER WELL HISTORY DATE 05/12/91 05/13/91 ETD 10870' 10870' PAGE 7 COMMENTS CONTINUED WORKING ON DRAW-WORKS BRAKES. PRESSURE TEST BOPE AS FOLLOWS: CHOKE MANIFOLD, SAFETY VALVES, AND UPPER PIPE RAMS TO 300 PSI (LOW) AND 3000 PSI (HIGH); ANNULAR PREVENTER TO 300 PSI (LOW) AND 2500 PSI (HIGH). PLAN TO TEST OTHER RAM PREVENTERS ON FIRST TRIP OUT OF THE HOLE. PULLED TEST PLUG TO RIG FLOOR AND REMOVED SAME. RAN IN TO LATCH RBP AT 9808' DPM. FOUND DRILL STRING PLUGGED. REVERSED OUT ONE DRILL STRING VOLUME. LATCHED RBP AND RAN INTO 10,475' DPM. RESET RBP TO ISOLATE HB-4 PERFORATIONS. TESTED CAC03 LCM SQUEEZE WITH COMPLETION FLUID. WOULD NOT HOLD PRESSURE. DECIDED TO RESQUEEZE. MIXED A 30 BBL CACO3 LCM PILL. DISPLACED PILL INTO LINER. SQUEEZED PILL INTO PERFORATIONS. RESQUEEZED FOUR TIMES-LAST TIME PRESSURE BLED FROM 3000 PSI TO 2500 PSI IN 50 MINUTES. RAN IN TO 10469' DPM. CIRCULATED OUT EXCESS CACO3 LCM PILL FILTERING RETURNS UNTIL THE PILL REACHED SURFACE. REPRESSURED SQUEEZED PERFORATIONS TO 2500 PSI WITH 7 BBLS OF COMPLETION FLUID. PRESSURE BLED TO 800 PSI IN 10 MINUTES. MIXED 30 BBL HIGH VIS PILL AND DISPLACED TO BALANCE WITH THE DRILL STRING HUNG AT 10469 ' DPM. PRESSURED PERFORATIONS TO 2500 PSI WITH 7 BBLS 'OF HIGH VIS PILL. PRESSURE BLED TO 1200 PSI IN 10 MINUTES. REPRESSURED WITH 4 BBLS AND PRESSURE BLED TO 1400 PSI IN 10 MINUTES. CIRCULATED OUT THE EXCESS PILL. RAN IN AND LATCHED HOWCO MODEL "N" BRIDGE PLUG AT 10474' DPM. CONTINUED IN AND TAGGED FILL AT 10699' DPM. PULLED OUT OF HOLE WITH BRIDGE PLUG. TESTED BOPE TO UNOCAL SPECIFICATIONS. RAN IN HOLE WITH 6" CLEAN OUT ASSEMBLY AND TAGGED FILL AT 10667' DPM. CIRCULATED DOWN TO 10739' DPM. CIRCULATED WELL CLEAN AND TRIPPED FOR FRAC ASSEMBLY. AUG 2 9 1991 Alaska Oil & Gas Cons. Commission ;Anchorage GRAYLING PLATFOI~q G--6RD NORKO~r~R Wa'~.?. HISTORY PAGE 8 ETD COMMENTS 05/14/91 10870' SERVICE AND PROGRAM SCHLUMBERGER MSRT DATA LINK TOOL AND BUNDLE CARRIER. RAN INAND SET FRAC PACKER WITH 15' TAIL AT 10498' DPM. RIGGED UP WIRELINE AND RAN BASELINE TEMPERATURE AND GAMMA RAY LOGS. RIGGED UP DOWELL SURFACE LINES. HELD. SAFETY MEETING TO DISCUSS FRAC WORK. TESTED SURFACE LINES TO 10,000 PSI. SPOTTED A 50 BBL SIZED SALT PILL AROUND THE PACKER TAIL INTO THE ANNULUS TO 8517' DPM TO PLUG "G" ZONE, HB-1, AND HB-2 PERFORATIONS. SETPACKERAND CLOSED BLIND RAMS. SQUEEZED AWAY THE SIZED SALT PILL UNTIL THE ANNULUS HELD 2500 PSI. PUMPED DATA FRAC AS FOLLOWS: PUMPED 160 BBL INJECTION TEST AT 15 BPM WITH 6900 PSI; PERFORMED STEP RATE INJECTION TEST; MONITORED TREATING PRESSURE FOR FRAC CLOSURE. RIGGED UP WIRELINE. o5/15/91 10870' CONTINUED TO RIG UP WIRELINE. RAN POST DATA FRAC TEMPERATURE/GAMMARAY LOGS. RAN MSRT DATA LINK TOOL AND RECOVERED DOWN HOLE PRESSURE DATA. RIGGED DOWN WIRELINE. RIGGED UP DOWELL SURFACE LINES. EVALUATED DATA FRAC DATA TO SIZE FRAC JOb. HELD SAFETY MEETING TO DISCUSS THE FRAC JOB. TESTED SURFACE LINES TO 10,000 PSI. 05/16/91 10864' PUMPED FRAC STIMULATION INTO HEMLOCK HB-4 AS FOLLOWS: 10 BBL OF 4 PPG; 48 BBL OF 10 PPG; 20 BBL OF 14 PPG. FINAL SURFACE INJECTION PRESSURE WAS 5700 PSI AT 15 BPM. PRESSURE DROPPED TO 3400 PSI IMMEDIATELY FOLLOWING SHUTDOWN. PRESSURE BLED TO 69 PSI IN 2 HOURS. PU~PED 20,293# OF 20/40 CARBOLITE PROPANT. RIGGED DOWN DOWELL. RELEASED THE PACKER AND REVERSED TWO DRILL STRING VOLUMES. CIRCULATED WELL TO BALANCE THE FLUID. PULLED OUT OF HOLE WITH THE FRAC ASSEMBLY. LAID DOWN THE FRAC ASSEMBLY AND RECOVERED THE DOWNHOLE DATA FROM THE MSRT DATA LINK TOOL. RAN IN HOLE WITH A BURNOVER SHOE AND TAGGED FILL AT 10538' DPM. CIRCULATED OUT FILL TO THE RETAINER AT 10,740' DPM. MILLED OVER THE RETAINER AND PUSHED THE JUNK TO 10,864' DPM. CIRCULATED WELL CLEAN. AUG t 9 lg91 Alaskm Oil & G~s Oons. Anchorage DAT~ 05/17/91 05/18/91 05/19/91 GRAYLING PLATFOP.~ G-6RD WORKOVER ~.L HISTORY PAGE 9 ETD COMMENTS 10864' CONTINUED CIRCULATING AND FILTERING BRINE TO 17 NTU'S TURBIDITY. DISPLACED WELL TAKING RETURNS DIRECTLY INTO THE PRODUCTION LINE. CIRCULATED AND FILTERED UNTIL RETURNS WERE 22 NTU'S TURBIDITY. PULLED OUT OF HOLE AND LAID DOWN BURNOVER SHOE. RIGGED UP SCHLUMBERGER WIRELINE. RAN GAUGE RING AND JUNK BASKET TO 10,860' WLM. TRIP WIRELINE FOR EZSV WITH BRIDGE PLUG KIT. 10864' RAN IN WITH EZSV ON WIRELINE TO 10415' DIL AND FIRED SETTING TOOL. RETAINER PARTIALLY SET AND SETTING TOOL WOULD NOT RELEASE. PULLED UP TO 9000# (70% OF BREAKING STRENGTH) TO PULL OUT OF ROPE SOCKET. RETAINER APPEARED TO MOVE UP HOLE SEVERAL FEET. WORKED WIRE AT 9000# AND WIRE PARTED AT SURFACE. WAITED ON WIRE ROPE SPEAR. MADE UP WIRE ROPE SPEAR FISHING ASSEMBLY AND RAN IN TO 2513' DPM. ROTATED TO CATCH FISH. PULLED OUT OF HOLE WITH SPEAR AND DRAG INCREASED TO 450K OVERPULL. COULD NOT GO BACK DOWNHOLE. RIGGED UPANDRANFREEPOINT-SPEARAND FIRST COLLAR STUCK. BACKED OFF ABOVE SECOND DRILL COLLAR. TOP OF FISH AT 1051' DPM. RAN IN WITH SPEAR AND ATTEMPTED TO RECOVER WIRE-NO GOOD. RAN IN WITH 15 EA 4-3/4" COLLARS, JARS, AND BUMPER SUB AND SCREWED INTO FISH AT 1051' DPM. 10864' FINISHED PICKING UP 4-3/4" COLLARS FOR FISHING ASSEMBLY. RAN IN AND SCREWED INTO FISH AT 1051' DPM. JARRED DOWN-NO GOOD. BACKED OFF AT BOTTOM DRILL COLLAR. TOP OF FISH AT 1079.50' DPM. RAN IN WITH SPEAR AND ATTEMPTED TO RECOVER WIRE-NO GOOD. RAN IN AND SCREWED INTO FISH. ATTEMPTED TO BACK OFF SPEAR-NO GOOD. BACKED OFF AT SCREW-IN SUB. DECIDED TO GET LARGER COLLARS AND JARS. TESTED BOPE TO UNOCALSPECIFICATIONS WHILE WAITING ON FISHING TOOLS. PICKED UP 15 EA 6-1/2" DRILL COLLARS, 6-1/4" DRILL COLLARS, 6- 1/4" SUPER JARS, 6-1/4" BUMPER SUB, AND SCREW-IN SUB. RAN IN ON 5" DRILL PIPE AND SCREWED INTO FISH. JARRED FISH DOWN HOLE 40' AND FISH CAME FREE. WORKED FISH UP HOLE. RECEIVED AU G 2 9 1991 Alaska 0il & Gas Cons. Com~SsJ-e~ Anchorage DATE 05/20/91 05/21/91 05/22/91 GRAYLING PLATFORM G-6RD WORKOVER WWr.T. HISTORY PAGE 10 ETD ~ 10870' CONTINUED TO WORK FISH UP HOLE. FISH BECAME STUCK AT 80' DPM. UNABLE TO MOVE UP OR DOWN. PICKED UP A STAND OF DRILL COLLARS (6-1/2") AND ATTEMPTED TO JAR DOWN-NO GOOD. PICKED UP SURFACE JARS ON TOP OF ONE STAND OF 6-1/2" DRILL COLLARS. JARRED FISH OUT OF HOLE. RECOVERED ENTIRE FISH AND ± 3000' OF WIRE ROPE. REARRANGED PIPE IN DERRICK AND LAID DOWN WASH PIPE. RAN IN HOLE WITH WIRE ROPE SPEAR FISHING ASSEMBLY. ENGAGED FISH AT 2645' DPM-RECOVERED 120' OF WIRE ROPE RAN IN AND ENGAGED FISH AT 3108' DPM- RECOVERED 600' OF WIRE ROPE. RAN IN AND ENGAGED FISH AT 3666' DPM. 10870' PULL OUT OF HOLE WITH SPEAR AND RECOVERED 550' OF WIRE ROPE. RAN IN HOLE TO 777' DPM. SERVICED RIGAND SLIPPED DRILLING LINE. CONTINUED IN HOLE TO 4224' DPM AND ENGAGED FISH- RECOVERED BALANCE OF WIRE ROPE. LAID DOWN 6-1/2" DRILL COLLARS AND SPEAR ASSEMBLY. MADE UP OVERSHOT WITH A 3-3/4" BASKET GRAPPLE. RAN IN AND ENGAGED FISH AT 10425' DPM. PULLED FISH FREE WITH 35K OVERPULL (SHEARED RUNNING TOOL OFF EZSV). PULLED OUT OF HOLE STRAPPING DRILL PIPE. LAID DOWN FISHING ASSEMBLY. 10870' RAN IN WITH BLADED MILL AND TAGGED RETAINER AT 10437' DPM. MILLED RETAINER AND PUSHED RETAINERJUNK TO 10858' DPM (ETD). CIRCULATED WELL CLEAN. TRIP FOR WIRELINE. CHECKED RIG BRAKES WHILE WAITING ON WIRELINE UNIT. RIGGED UP WIRELINE AND RAN IN WITH 6.05" OD GAUGE RING AND JUNK BASKET. SET DOWN AT 10139' DIL. ATTEMPTED TO WORK BY TIGHT SPOT - NO GOOD. TRIPPED TO CHECK JUNK BASKET - FULL OF WIRE ROPE DEBRIS. RIGGED DOWN WIRELINE. RAN IN HOLE WITH BIT AND SCRAPER TO 10858' DPM. CIRCULATED WELL CLEAN AT 11 BPM FILTERING RETURNS. TRIP FOR WIRELINE. R£CEIVED Alaska Oil & Gas Cons. Commission AnChorage DATE 05/23/91 05/24/91 GRAYLING PLATFORM G-6RD WORKOVER WELL HISTORY PAGE 11 ETD COMMENTS 10870' CONTINUED TO PULL OUT OF HOLE WITH BIT AND SCRAPER. RIGGED UPWIRELINE AND RAN IN HOLE WITH 6.05" OD GAUGE RING AND JUNK BASKET. SET DOWN AT 10141' WLM. TRIP FOR 5.6875" GAUGE RING. RAN IN HOLE TO 10500'WLM. TRIP FOR CEMENT RETAINER. MADE UP RETAINER WITH BRIDGE PLUG KIT ON WIRELINE SETTING TOOL. RAN IN HOLE AND SET RETAINER AT 10417' DIL. PULLED OUT AND RIGGED DOWNWIRELINE. MADE UP AN RTTS SQUEEZE PACKER AND RAN IN HOLE. TAGGED RETAINER AT 10,433" DPM (16' CORRELATION FROM DIL TO DPM). PICKED UP 5' AND SET THE PACKER. PRESSURE TESTED THE RETAINER TO 3000 PSI FOR 15 MINUTES, RELEASED PACKER. CIRCULATED AND FILTERED COMPLETION FLUID TO 69 NTU'S AT THE FLOWLINE. TRIP FOR PERFORATING ASSEMBLY. 10870' CONTINUED TRIP OUT FOR PERFORATING ASSEMBLY. MADE UP TCP GUN ASSEMBLY AND RAN IN HOLE FILLING DRILL PIPE FORAN 800 PSI UNDERBALANCE. RIGGED UP WIRELINE. RAN IN WITH A GR/CCL LOG TO TIE IN THE GUNS TO DIL LOG DATED 4/14/82. SET PACKER AND RAN CONFIRMATION LOG. PRESSURE TESTED SURFACE LINES TO 3000 PSI. SHOT A FLUID LEVEL TO CONFIRM THE UNDERBAI2%NCE. LOADED THE FIRING BAR AND RIGGED UP SHOT DETECTION EQUIPMENT. DROPPED FIRING BAR AND PERFORATED HEMLOCK HB-1 FROM 10368' TO 10398' DIL WITH 25 GRAM, DEEP PENETRATING CHARGES, LOADED IN 4 5/8" OD CARRIERS AT 8 HPF SHOT DENSITY. OPENED THE PACKER BYPASS AND REVERSED OUT ONE DRILL STRING VOLUME. CIRCULATED WELL THE LONG WAY TO BALANCE OUT BRINE WEIGHT. CHECKED WELL FOR FLOW-STATIC. RIGGED DOWN SURFACE LINES. PULLED OUTANDLAID DOWN TCP GUN ASSEM~LY ALL SHOTS FIRED. MADE UP ~AC ASSEMBLY AND RAN IN HOLE. RECEIVED AUG g lggl Alaska Oil & Gas Cons. Commissien Anchorage. DATE 05/25/91 05/26/91 GRAYLING PLATFORM G-6RD WORKOVER WELL HISTORY PAGE 12 ETD COMMENTS 10870' CONTINUED RUNNING IN HOLE WITH FRAC ASSEMBLY. SET SQUEEZE PACKER AT 10240' DIL (10256' DPM). RIGGED UP WIRELINE. RAN BASE LINE TEMPERATURE LOG. PULLED OUT AND RIGGED DOWN WIRELINE. MADE UP DOWELL SURFACE LINES, SPOTTED A 50 BBL SIZED SALT PILL ACROSS THE "G" ZONE PERFORATIONS THROUGH THE "RTTS" BYPASS. SQUEEZED PILL AWAY UNTIL THE ANNULUS HELD 2500 PSI. HELD SAFETY MEETING TO DISCUSS THE FRAC JOB. TESTED DOWELLSURFACE LINES TO 10000 PSI. PUMPED "DATA FRAC". RIGGED UP SCHLUMBERGER WIRELINE. RAN POST "DATA FRAC" GR/TEMPERATURE LOG. RAN "MSRT" LINK TOOL TO RECOVER DOWNHOLE PRESSURE DATA - TOOL FAILED. RIGGED DOWN SCHLUMBERGER. REVERSED OUT GEL AND SIZED SALT PILL. PULLED OUT WITH FRAC STRING TO RECOVER PRESSURE DATA FROM BACKUP GAUGES. 10870' CONTINUED TRIP OUT TO RECOVER PRESSURE DATA FROM BACKUP GAUGES. LAID DOWN "MSRT LINK TOOL. RECOVERED DATA FROM GAUGES. SERVICED GAUGES AND BUNDLE CARRIER. RAN IN WITH FRAC ASSEMBLY AND SET RTTS PACKER AT 10240' DIL (10256' DPM). SPOTTED A 50 BBL SIZED SALT PILL ACROSS THE "G" ZONE PERFORATIONS THROUGH THE RTTS BYPASS. SQUEEZED PILL AWAY UNTIL THE ANNULUS HELD 2500 PSI. HELD SAFETY MEETING TO DISCUSS THE FRAC JOB. TESTED DOWELL SURFACE LINES TO 10000 PSI. PUMPED FRAC JOB AS FOLLOWS: 130 BBL PAD; 28 BBL 4#/GAL PROPPANT; 32.3 BBL 10#/GAL PROPPANT; 55 BBL 15#/GALPROPPANT; AND 157 BBL OF DISPLACEMENT GEL. PUMPED A TOTAL OF 35,000# OF 20-40 CARBOLITE PROPPANT (32,000# PROPPANT THRU THE PERFS). WAITED ON SURFACE PRESSURE TO DISSIPATE. REVERSED OUT DISPLACEMENT GEL AND EXCESS SALT PILL. PULLED OUT OF HOLE AND LAID DOWN FRAC STRING. MADE UP A MILL AND RAN IN HOLE TO LINER LAP. WORKED ON DRAWWORKS BRAKES. CONTINUED RUNNING IN HOLE. R£CEIVED Alaska Oil & Gas Cons. Commission Anchorage, GRAYLING PLATFORM G-6RD WORKOVER WELL HISTORY PAGE 13 DATE MW ETD 05/27/91 10854' COMMENTS TAGGED SAND AT 10288' DPM. WASHED SAND TO 10417' DIL. DRLD BRIDGE PLUG AND PUSHED JUNK TO 10854' DPM. CIRCULATED WELL CLEAN. TRIP PERMANENT PRODUCTION PACKER. RAN"I'N WITH A 7" OTIS "BWH~ PACKER ON A HYDRAULIC SETTING-TOOL TO 10290' DPM. SET PACKER WITH 2800 PSI AND SETTING BALL SHEARED OUT EARLY. SHEARED OFF PACKER WITH 40K OVERPULLAND TRIPPED FOR A TESTS~ ASSEMBLY. MADE UP SEALS AND RAN IN HOLE. STABBED INTO THE PACKER 10290' DIL (10306' DPM). TESTED THE PACKER AGAINST THE FORMATION TO 1000 PSI. TRIP FOR "JP" PACKER PLUG. 05/28/91 10854' CONTINUED TO PULL OUT OF HOLE WITH TEST SEAL ASSEMBLY. PULLED WEAR BUSHING AND RAN TEST PLUG. TESTED BOPE TO UNOCAL SPECIFICATIONS. PULLED TEST PLUG AND SET WEAR BUSHING. MADE UP "JP" PLUG FOR OTIS "BWH" PERMANENT PACKER. RAN IN HOLE ON DRILL PIPE AND SET PLUG IN PACKER AT 10,306' DPM (10,290' DIL). RIGGED UP TO FILTER BRINE. FILTER PACKED OFF DUE TO POLYMER IN BRINE SYSTEM. SHIPPED SURFACE SYSTEM FLUID TO TBU ONSHORE FACILITY. MIXED AND FILTERED A NEW 3% KCL/FIW BRINE IN THE SURFACE SYSTF2~. DISPLACED THE WELL BORE WITH CLEAN BRINE TAKING RETURNS TO TBU ONSHORE FACILITY. BUILT ADDITIONAL SURFACE VOLUME. CIRCULATED AND FILTERED FLUID. 05/29/91 10854' i 'E EIVE'D CONTINUED TO CIRCULATE AND FILTER FLUID. PULLED OUT OF HOLE WITH THE "JP" PLUG RUNNING TOOL. MADE UP 4 5/8" VANN SYSTEMS TUBING CONVEYED PERFORATING ASSEMBLY ANDRANIN HOLE ON TAPERED DRILL STRING. LEFT THE LAST 5400' OF PIPE DRY TO ACHIEVE 800 PSI UNDERBALANCE FOR PERFORATING. RIGGED UP SURFACE LINES AND MANIFOLD. TESTED SURFACE LINES. RIGGED UP WIRELINE. RAN GAMMA RAY CORRELATION LOG AND SPOTTED GUNS ON DEPTH. SET THE PERFORATING PACKER AND RAN A CONFIRMATION LOG. RIGGED DOWN WIRELINE. DROPPED THE FIRING BAR AND PERFORATED THE FOLLOWING "G" ZONE INTERVALS WITH 25 GRAM "DEEP PENETRATING" CHARGES AT 8 HPF: G-2, 9,947'-9,972'DIL; G-3, 10,014'- 10,045' DIL' G-4, 10,072t- 10,105'DIL' G-5, 10,172'-10,227'DIL. RELEASED THE PERFORATING PACKER AND REVERSED TWO DRILL STRING VOLUMES. CIRCULATED BOTTOMS UP THE LONG WAY. RIGGED DOWN SURFACE LINES AND MANIFOLD. PULLED OUT OF HOLE WITH PERFORATING ASSEMBLY. GRAYLING PLATFORM G-6RD WOI~KO%rE~ WELL HISTORY DATE MW ETD 05/30/91 10854' 05/31/91 10854' 06/1/91 PAGE 14 COMMENTS FINISHED LAYING DOWN TUBING CONVEYED PERFORATING GUNS (100% FIRED). RAN IN WITH "JP" PACKER PLUG RETRIEVING TOOL. CIRCULATED BOTTOMS UP AND LATCHED THE PLUG AT 10,306' DPM. PULLED OUT OF HOLE LAYING DOWN 3 1/2" DRILL PIPE AND 4 3/4" DRILL COLLARS. PULLED THE WEAR BUSHING. CHANGED OUT PIPE RAMS TO DUAL 3 1/2" BLOCKS IN TOP CAVITY AND SINGLE 2 7/8" BLOCKS IN BOTTOM CAVITY. TESTED THE DOOR SEALS TO 3000 PSI. RIGGED UP HANDLING TOOLS TO RUN THE TRIPLE GAS LIFT PRODUCTION COMPLETION. RAN IN WITH COMPLETION HYDROTESTING EQUIPMENT TO 5000 PSI. CONTINUED TO RUN DUAL 3 1/2" GAS LIFT PRODUCTION COMPLETION WITH SIDE STRING AND GASLIFT MANDRELS BELOW THE TRIPLE PACKER HYDROTESTING TO 5000 PSI. CONTINUED TO RUN DUAL 3 1/2" GAS LIFT PRODUCTION COMPLETION WITH SIDE STRING AND GASLIFT MANDRELS BELOW THE TRIPLE PACKER HYDROTESTING TO 5000 PSI. INSTALLED CONTROL LINES TO SSSV NIPPLES AND TEST SAME TO 5000 PSI. CONTINUED IN AND STABBED INTO THE PERMANENT PACKER AT 10,290' DIL. UNSTABBED FROM THE PERMANENT PACKER, SPACED OUT THE DUAL 3 1/2" TUBING STRINGS, INSTALLED THE DUAL SPLIT HANGERS, AND LANDED THE COMPLETION BY STABBING THE SEAL ASSEMBLY BACK INTO THE PERMANENT PACKER. PRESSURED THE LONG STRING TO 200 PSI LOOKING FOR ANNULAR RETURNS TO CONFIRM THE PERMANENT PACKER SEALS ARE HOLDING. RIGGED DOWN TUBING RUNNING EQUIPMENT. RIGGED UP SLICKLINE ON THE SHORT STRING. RAN IN WITH AN "XN" PLUG AND SET SAME IN THE NO-GO NIPPLE IN THE SHORT STRING TAIL. PRESSURED THE SHORT STRING TO 3500 PSI AND SET THE TRIPLE PACKER AT 8,400'TM. RECOVERED THE "XN PLUG AND RIGGED DOWN SLICKLINE. PUMPED DOWN THE SHORT STRING LOOKING FOR RETURNS ON THE ANNULUS OR LONG STRING. PUMPED AT 1.7 BPM WITH 200 PSI AND HAD RETURNS ON THE LONG STRING INDICATING THAT THE TRIPLE PACKER OR SIDE STRING BELOW THE TRIPLE WAS NOT HOLDING. GRAYLING PLATFORM G-6RD WORKOVER WELL HISTORY PAGE 15 DATE ETD COMMENTS 06/02/91 10854' PUMPED DOWN THE SHORT STRING WITH THE LONG STRING SHUT IN LOOKING FOR RETURNS ON THE ANNULUS. PUMPED AT 1.7 BPM WITH 250 PSI AND HAD RETURNS ON THE ANNULUS. RIGGED UP TO PULL THE COMPLETION. PULLED THE TRIPLE PACKER LOOSE WITH 35 K OVERPULL. PULLED OUT OF HOLE STANDING BACK THE DUAL 3 1/2" COMPLETION. FOUND THE SIDE STRING BELOW THE TRIPLE PACKER PARTED AT THE TOP OF THE SECOND GASLIFT MANDREL. CONTINUED PULLING OUT OF HOLE LAYING DOWN SIDE STRING/LONG STRING. 06/03/91 10854' CONTINUED TO PULL OUT OF HOLE LAYING DOWN LONG STRING AND GAS LIFT SIDE STRING. REDRESSED OTIS SEAL ASSEMBLY AND BAKER DUAL HYDRAULIC RETRIEVABLE PACKER. DECIDED TO COMPLETE THE WELL AS A STANDARD DUAL 3 1/2" COMPLETION. RIGGED UP TO RUN COMPLETION. RAN IN HOLE WITH DUAL 3 1/2" GAS LIFT COMPLETION HYDROTESTING TO 5000 PSI. 06/04/91 10854' CONTINUED TO RUN IN DUAL 3 1/2" GAS LIFT COMPLETION HYDROTESTING TO 5000 PSI. MADE UP SSSV NIPPLES WITH DUMMY VALVES AND TESTED CONTROL LINES TO 5000 PSI. CONTINUED IN HOLE AND STABBED INTO THE PERMANENT PACKER AT 10,240' DIL (10,306' DPM). SPACED OUT TUBING STRINGS ANDLANDED DUAL SPLIT HANGERS. TESTED PERMANENT PACKER SEALS - OKAY. RIGGED DOWN TUBING HANDLING EQUIPMENT. RIGGED UP SLICKLINE ON THE LONG STRING. RETRIEVED THE SSSV DUMMY VALVE. RAN IN WITH "X" PLUG AND SET SAME IN THE "XA" SLEEVE AT 10,283 TM. 06/05/91 10854' RECEIVED ALJ 9 t991 PULLED OUT OF HOLE WITH SLICKLINE - STILL HAD PLUG. RAN IN AND SET PLUG IN THE "XA" SLEEVE AT 10,283' TM. PULLED OF HOLE - PLUG SET. PRESSURED THE LONG STRING TO 3,500 PSI AND SET THE DUAL PACKER. PRESSURE TESTED THE SHORT STRING AGAINST THE "G" ZONE PERFORATIONS TO 350 PSI TO CONFIRM THE DUAL PACKER WAS SET. REMOVED THE "X" PLUG FROM THE LONG STRING. RIGGED DOWN SLICKLINE. PULLED THE LANDING JOINTS AND SET THE BACK PRESSURE VALVES. NIPPLED DOWN THE ROPE. INSTALLED THE DUAL3 1/2" PRODUCTION ~ v v ...-~aseons.~omm'm~en TREE. PACKED OFF THE DUAL SPLIT Alaska Oil ,& - TUBING HANGERS. TESTED HANGERS AND ~hO[~ SEALS TO 5000 PSI. INSTALLED PRODUCTION SURFACE LINES. PULLED BACK PRESSURE VALVES. RELEASES RIG TO TBUS G-32 WORKOVER AT 1200 HOD-RS ON 6/5/91. I 16" 75# J-55 @ 631' ~-~/8" @ 3036' RKB - 0.00' TBG HGRS O 42.85' TUBING DETAIL: LS: 3-1/2", 9.2#, N-80 BUTTRESS (SP CL) 2-7/8", 6.4#, N-80 BUTTRESS (SP CL) SS: 3-1/2'", 9.2#, N-80, BUTTRESS (SP CL) ~ SHORT STRING A) OTIS 3-1/2" $$5"V · 316' B) PTA '~SO" GLM'S O.M ~1 · 2813' ~.M #2 · 4510' GLM #3 · 6025' O.M #4 e 6700' ~.M #5 · 7254' GLM #6 ~ 7809' GLM #7 0 8297' C) OTIS 3-1/2" "Y,A" SLEEVE 0 8313' B) BAKER BUN. PKR · 8352' E) OTIS 2-7/8" '~N" NIPPLE · 8400' F) 2-7/8" RE-ENTRY GUIDE · 8402' LONG STRING 1) OTIS 3-1/2" SSSV 0 318' 2) PTA '~SO" GLM'S O.U #1 · 2874' O.M #2 · 4764' O.U #3 · 5872' GLU #4 '~ 6904' GLM #5 · 7623' eLM #6 · 8273' 3) OTIS 3-1/2" "XA" SLEEVE 0 8329' 4) BAKER DUAL PKR · 8360' 5) 3-1/2"x 2-7/8" X-OVER . 9928' 6) 2-7/8" STEEL BLAST ,JT$ (3.5 OD) F/ 9929~ TO 10283' 7) OTIS 2-7/8" "XA" SLEEVE · 1028;3' 8) 2-7/8" STP SLOT LOCATOR & SEAL ASSY F/ 10318' TO 10359' 9) OTIS 2-7/8" "X" NIPPLE e 103e0' 10) 2-7/8- RE-ENTRY GUIDE · 10394' 11) OTIS '~I/H" PERM PKR · 10306~3PM 7" 29# N-80 TOL @ 8509' 9-5/8" 47# N-80 @ 8922' 7" L @ 11000' ETD = 10854 11 "G" ZONE: G-2 9947'- 9972' G-3 10014'- 10046' G-4 10072'- 10105' G-5 10172'- 10227' HEMLOCK ZONE: J ECEIVED A U G 2 9 1991 Alas/~!.0il & Gas Cons. Commi Anchorage HB-1 10368'- 10400' FRAC W/ 32,000# 20-40 MESH CARBOLITE HB-2 10421'- 10441' HB-4 10562'- 10682' FRAC W/ 20,300# 20-40 MESH CARBOLITE WELL TBUS G-6RD COMPLETION ( 6-4-91 ) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE' NONE DATE' 8-7-9 1 sslen STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging m Time extension __ Stimulate ~ Pull tubing ~ Variance __ Perforate __ Other ...X. Name of rat r . . (Ul~O~.e)of Well' ~hlon [(~)iP~ ~ompany of California ' I --Devel~ment~ ............. ~ Exploratory 3. Address ~ Stratigraphic ~_~_ R~w 1qO247: Ankh.: AK: 99519-~247 Service 4. Location of well at sudace Leg # 2, Conductor # 46 1879' FSL & 1385' FEL, Sec. 29, T9N, R13W, SM At top of productive interval Top of "G" zone at 9950' MD 365' FSL & 2418' FWL, Sec. 28, T9N, R13W, SM At effective depth 10,870' MD 356' FSL & 2559' FWL, Sec. 28, T9N, R13W, SM At total depth 11,0 O0 ' MD 358· FSL & 2585' FWL, Sec. 28, T9N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 11,000 ' feet Plugs(measured) 9,759 ' feet Effective depth: measured 10,870 ' feet Junk (measured) true vertical 9,632 ' feet Casing Structural 356 ' Conductor 631 ' Sudace 3036 · 9895 · Intermediate 2491' Production Liner Perforation depth: measured true vertical 6. ~:3~ el~io~59r~B~4LLW feet 7. Unit or Property name Tradinq Bay Unit 8. Well number G-GRD 9. Permit number 82-33 10. APl number 50-- 733-20073-01 3ne/West Forela] Length Size Cemen~d 26" DRIVEN 16" 1450 SXS 13-3/8" 1250 SXS 9-5/8" 2200 SXS 7" 600 SXS Measured depth ~ ,.: ~,,t;,~,,,: ~ ve~lca depth 356~ 356~ 631~ 63~~ 3036~ 2879~ 9895 ~(~ZRDO~ ~ 89~7 ~) 8672 ~ 8509 ~-11~000 ~ 7374 ~-9763 9950'-9970'; 10030'-10045','10075'-10105'; 10175'-10195'; 10370'-10400' ;10421'-10441' 8727'-8747'; 8806'-8821'; 8851'-8880'; 8949'-8969'; 9141'-9171'; 9190'-9210' ~bing(size, grade, andmeasureddepth) 3-1/2", 9.2#, N-80 Butt; SS @ 8467' LS @ 10309' Pac~rsandSS~ypeandmeasureddep~ker A-5 dual @ 8430'; Baker F-1 @ 10292'; Otis SSSV SS @ 297' LS @ 293' 13. Attachments Description summary of proposal ...x.. Detailed operations program ~ BOP sketch ~._ 14. Estimated date for commencing operation November 30, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil .;:L Gas __ Suspended __ Service 17' I hereby certifY that the f°reg°i~"~true and c°rr~ ~°,~e(~st °f mY kn°wledge', Signed Gja~R¥ S' B~~, ~ Title R~GIONAL DRILLING ~N~G~ (% 0" FOR COMMISSION USE ONLY Conditions of approval: Notify Commi~on so representative may Witness ~ Approval No. Plug integrity __ BOP Test __ Location clearance __ I Mechanical Integrity Test __ Approved by order of the Commission Subsequent form required 10- Approved Copy Form 10-403 Rev 06/15/88 Commissioner ORIGINAL SIGNED BY LONNIE C, SMITH SUBMIT IN TRIPLICATE WORKOVER PROCEDURE TBUS G-6RD (9-10-90) · · · · · · · · 10. 11. 12. 13. 14. 15. 16. MOVE RIG 54 OVER TBUS G-6RD, LEG 2, CONDUCTOR 46. KILL WELL,REMOVE TREE, INSTALL AND TEST BOPE. PULL AND LAY DOWN DUAL G/L PRODUCTION STRING. MILL OVER AND RECOVER PERMANENT PACKER AT 10292'. CLEAN OUT WELLBORE TO 11000' ETD. PRESSURE TEST 9-5/8" CASING. CHANGE OVER TO COMPLETION FLUID AND PERFORATE HB-1 AND 4. FRACTURE STIMULATE HB-4 AND HB-1. CLEANOUT WELLBORE TO 11000' ETD. SET PERMANENT PACKER AND ISOLATION PLUG AT 10300'. CHANGE OVER TO COMPLETION FLUID AND PERFORATE "G" ZONE. RECOVER PERMANENT PACKER PLUG. RUN DUAL G/L COMPLETION. REMOVE BOPE AND INSTALL DUAL TREE. RETURN WELL TO PRODUCTION AND MOVE OFF. WIRELINE PERFORATE HB-3 AFTER PRODUCTION RATE HAS STABILIZED. NOTE: SBHP ANTICIPATED TO BE 4025 PSI AT 9450' TVD. WORKOVER FLUID WILL BE FILTERED INLET WATER WITH NACL AS REQUIRED FOR WELL CONTROL. 3" KILL LINE WITH TWO 3" 5M VALVES [ d) ...... ~'J~ KILL LINE FROM MUD PMP · CEMENT UNIT BELL NIPPLE 13-5/8" ,3000 PSI ANNULAR ! PIPE RAMS BLIND RAMS I '1 PiPE RAMS i FLOWLINE 13-5/8" 3M FLANGE ADAPTER 3M x 5M 13-5/8" 5M FLANGE DOUBLE GATE 5M I 1;3-5/8" 5M FLANGE J 4." CHOKE LINE WiTH ONE REMOTE & 1 MANUAL 4" 5M VALVE ........ ~_1,~ ....... ',J · · CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE RISER I I 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M SPOOL 13-5/8" DOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCA.L) DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 11/26/89 16" @ 631'J @ 3036' Z 7" TOL @ 8509' 9-5/8" @ 8922' 8 TUBING DETAIL' LS: 3-1/2", 9.2#, N-80 BUTT SS: 2-7/8", 6.4#, N-80, BUTT 1) SUBSURFACE SAFETY VALVE 2) GAS LIFT MANDRELS 3) "XA" SLIDING SLEEVES 4) "XN" LANDING NIPPLE 5) RE-ENTRY GUIDE 6) "X" LANDING NIPPLE 7) RE-ENTRY GUIDE 8) DUAL PACKER @ 8450' 9) PERMANENT PKR @ 10300' :i.~; ;,, i! ..... il ~/i', ' :: "G" ZONE: 0-2 9947'- 9972' O-3 10014'- 10046' G-4 10072'- 10108' G-5 10172'- 10228' 7" L @ 11000' //] HEMLOCK ZONE' HB-1 10368'- 104-00' FRAC HB-4 10562'- 10682' FRAC WELL TBUS G-6RD PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE' NONE DATE' 9- 10-90 WELL TEUS G-6RD CASING & ABANDONMENT DETAIL ~ ~ ~, ' II.) Bual lubing Hanger at 33.60' Ii ~ . iii.) 16', 75~, J-55 Casing at 631' ' I I i, IV.) 13 3/8', 61~, J-55 Casing at 3036' p GL~.~_. '~L"'~' ~2 V.) Top 7', 29~', N-80 Liner at 8509' I_V. _ VI.) Window at 8917' to 8977' with KOP at 8917' ' ~[ GL---A -.3 VII.) 9 5/8", 47-~, N-80 Casing Plugged Back ~ ~L._.~.~ -- at 8922' VIII.) Bottom 7', 29~', N-80 Liner at 11,000' : TUBING DETAIL GLM i 'D GLM-"-- ~ ' LONG STRING: 3 1/2'; 9.2~, N-80 TUBING i 1.) Otis 'XEL" NiPl~le at 292.65' ~ 2.) McMurray 'MN' Gas Lift Mandrel at 2007.54' ~E GL.._~.~ ~ ~5 3.) McMurray 'MN' Gas Lift Mandrel at 3387.54' 4.) McMurray 'MN' Gas Lift Mandrel at 4668.54' ~ GL---~ (~L'--"~- .S 5.) McMurray 'MN' Gas Lift Mandrel at 5694.54' ~ 6.) McMurray 'MN' Gas Lift Mandrel at 6780.54' ~ 7.) McMuray 'MN' Gas Lift Mandrel at 7658.45' i - 8.) McMurray 'MN' Gas Lift Mandrel at 8359.52' : ~r~'-c~. 7 9.) otis 'XA° Sleeve at 8395.78' 10.) Baker Model 'A-5' Packer from 8429.52' ~ to.8442.26' o ~L--'~ ~ 8 11.) Blast Joints from 9947.47' to 10,006.45' ~~ 12.) Blast Joints from 10,037.08' to 10,135.35' H__x'"~" xA 9 13.) Blast Joints from 10,165.53' to, 10,224.52' 15) 14:) Otis 'XA° Sleeve at 10,254.37 --~lo Locator Sub at 10,291.94' I i 16.) Baker Model 'F-I' Packer with Seal Assembly j ~ from 10,292.44' to 10,308.33'. Packer at ~' ; 10,292'(DPM) i 17.) Bottom Wireline Entry Guide at 10,309.00' v --;. ~ ~ SHORT STRING: 2 7/8", 6.4#, N-80 TUBING ~ A,) Otis 'XEL' Nil3ple at 297.11' B.) Camco 'KBMG' Gas Lift Mandrel at 2009.00' ;I C.) Camco ~KBMG' Gas Lift Mandrel at 3445.00' vi vii ~~1. i ~ Camco 'KBMG' Gas Lift Mandrel at 4716.00' Camco 'KBMG' Gas Lift Mandrel at 5963.00' -=-=-- I 11 F.) Camco 'KBMG' Gas Lift Mandrel at 7142.00' G.) Camco 'KBMG' Gas Lift Mandrel at 8372.00' ~-- H.) Otis 'XA' Sleeve at 8408.40' ==_--- , 12 I.) Baker Model 'A-5' Packer from 8429.52° i to 8442.26' ==II.___~ J.) Bottom of Otis 'XN' NiDpIe at 8467.00' ~----- '~ PERFORATION RECORD ! xA__ *~ ,~ I DA TE INTERVAL CONDITION 16 10030'-10045' G-3 Production 10075'-10105' G-4 Production '~ I I 10175'-10195' G-5 Production ~?~ 9183 · 10,370'- 10,400' HBo1 Production- 9/83. · 10421'-10441' HBo*2 Production __ NOTE:*SUBTRACT 2' FROM DIL TO GET CBL DEPTHS VIII __ , ,,, WELL SCHEMATIC '- UNION Oil. COMPANY OF CALIFORNIA · ANCP, O~qAGE, ALAS1(& ~ETg i SHEET , ,,,, , DV COLLAR, 4218' TOP CMT, 4729' TOP PLUG, 8922' WELL TBUS G-6RD CASING & CEMENT DETAIL VOLUMES SHOWN ARE (CMT. VOL./HOLE VOL.) TOP CEMENT AT 145' 26', 1' WALL, DRIVEN TO 356' .. 16', 75~', J-55 CSG AT 631' 1450sxs (1668f't'~/963ft~) '. GOOD CMT RETURNS TO SURFACE TOP CMT, 1518° " · ,. 13 3/8', 61~', J-55 CSG iT 3036' 1250sxs (2275ft'/2314ft') LOST PARTIAL CIRCULATION WHILE CEMENTIN'G TOP 7',29~,N-80 LINER AT 8509' " · WINDOW MILLED IN 9 5/8' CSG, 8917'-8977' .. ,. BTM PLUG, 9152 TOP 7',29~,N-80 LINER AT-.9750' 9 5/8';40~,43.5~, 47~;N-80&P- 110 CSG AT 9895' 2200sxs (2530ft 3/3208ft~) FULL RETURNS COMP. 3/1/68 COMP. 5/19/82 7',29-,N-80 LINER AT 11000 600sxs (690ft~13291t~) LINER & LAP TESTED OK TO 3000psi 7',29~,N-80 LINER AT 11429' 470sxs (540ft~/217ft~) NOTE: ALL CEMENT TOPS ARE THEORETICAL .. GRAYLING PLATFORM CASING & CEMENT DETAIL UNION OIL COMPANY OF CALIFORNIA ~CALE NONEs C~<D. ~_ 6/24/85 1. Operations performed: K%~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS Operation shutdown __ Stimulate __ Plugging __ Perforate Pull tubing __ Alter casing __ Repair well __ Pull tubing __ 2. Name of Operator ! 5. Type of Well: Union 0il Company of California (UNOOAI) Development__ Exploratory __ 3. Address ! Stratigraphic ~ P.O. Box 190247~ Anch~ Ak. ~ 99519-0247! Service__ 4. Location of well at sudace Cond. 76, Leg 2, 1879'N & 1383'W of SE Cor. Sec. 25), Other Datum elevation( or KB) 6. RT 99' HSI'DF 7. Unit or Property name TBU 8. Well number G-6rdL feet 19 Ri W S At tol~l~f pro'~ulctlve, ~erval 372'N & 2405'E of SW corner, Sec. 28, At effective depth i525'S & 3942'E of surface location TgN, R13W, SM At total depth 362'N & 2571'E of SW corner~ Sec. 28, TgN, R13W, SM 12. Present well condition summary Total depth: measured 11,000 ' feet Plugs (measured) true vertical 9., 775 ' feet Effective depth: measured 10,870 ' feet Junk (measured) true vertical 9,632 feet 9. Permit number/approval number 8-347 10. APl number 50-- 733-20073-01 11. Field/Pool McArthur River Field Casing Length Size Cemented Measured depth True vertical depth Structural 356 ' 26" Driven 356 ' 3.56 ' Conductor 631 ' 16" 1450 sx 631' 631 ' Surface 3,036 ' 13 3/8" 1250 sx 3,036 ' 2,879 ' Intermediate 9,895' 9 5/8" 2200 SX 9,895' 8,672' Production 2,491 ' 7" 600 SX 8,509-11,000 ' 7,374 ' -9,763 ' Liner Pedoration depth: measured 9950, -9970 '; 10,030 ' -10,045 '; 10,075 ' -10,105 '; 10,175 ' -10,195 ' l0,370 ' -lC, 400 '; l0,421 ' -lC, 441 '; l0,562 ' -lC, 609 ' true vertical 8727' -8747'; 8806' -8821 '; 8851 ' -8880 '; 8949 ' -8969 '; 9141 ' -9171 ' Tubing (size, grade, and measured depth) 3 1/2" 9 2# N-80 S 10,280' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. BaKer A-5 8430'-8442'; Baker F-1 $ 10,292' Otis sssv $ 293 I: ¢' i:: I V i:: I Intervals treated (measured) Treatment description including volumes used and fin al pressure Prior to well operation JAN 1 8 t989 Representative Daily Average ProduCtion or Injection D~i~''~ .... OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 162 216 350 1190 150 Subsequent to operation 146 168 457 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed rts Title Environmental Engineer 1200 100 16. Status of well classification as: Oil __~ Gas_ Suspended __ Service Date 1/12/89 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. 1 LEASE DATE 8/13/88 8114/88 8/15/88 ., 9/2/88 0064C Tradinq Bay Unit State E.T.D. 10,622 10,635' 10,633' 10,653' W E L L NO, G-6 RD/L% I E LO,, Mc Arthqr River DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Rigged up Otis 1-1/4" coiled tubing. Make up 2.7" flat bottom mill on a 1.75" mud motor. Rressure test lubricator and Otis BORE to 3000 psi. Ran in hole, tubing clear, tag fill at 10,589' and attempt to clean out (negative). Rulled out of hole. Mud motor locked up. Changed out mud motor and ran in hole. Clean out fill from 10,589'-10,622'. Mud motor stalling out when tagging bottom at 10,622'. Pulled loose after working with 6500# overpull. Rulled out of hole. Pulled out of hole. Make up 2.25" down jet nozzle with (14) .052" jets. Ran in hole clean out from 10,622'-10,633' Unable to clean out past 10,633". Pulled out of hole. Made up Hydro'Blast side jet cleaning tool with (9) .40" jets and pressure control indexer. Ran in hole cleaning tubing .5 to 75 BRM at 5000 psi, 26'/min to 10,309'. Circulate clean, stop pumping tJ index tool. Pulled out of hole cleaning the tubing. Checked tool, tool had indexed on bottom. Ran in hole cleaning tubing on pass #3. At the tail, circulate clean and stop pump for 2 hours to index tool. Repair HOWCO pump (additional one hour). Pull out of hole cleaning tubing on final pass #4. Rig down Otis equipment and rig up Myers wireline. Ran in hole with 2.735" swedge, slight obstruction at 8,421'. continue to tail at 10,309' and out to 10,585'. FUlled out of hole and rig down Myers wireline. Release rig at 2400 hours. Rigged up Schlumberger wireline unit. Tested lubricator to 2500 RSI, ok. Ran in hole with 2-1/8" flow-jet strip guns 4 SRF and perforated the following intervals 10,370'-10400' (Hemlock Bench One), 10,562'-10,609' (Hemlock Bench Four). fv~1'oSIO N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ,~ Re-enter suspended well [] Alter casing ~,. Time extension ~ Change approved program ~ Plugging ~ Stimulate E3 Pull tubing ~ Amend order [] Perforate ~ Other 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 19024.7,.. Anch, Ak., 99519-0247 4. Location of well at surface Cond. 76, Leg 2, 1879'N & 1383'W of SE Cot. Sec. 29, At top ~¢ool~Jc~ irrt~rval 372'N & 2405'E of SW corner, Sec. 28, TgN, R13W, SM At effective depth 1525'S & 3942'E of surface location At total depth 362'N & 2571'E of SW corner, Sec. 28, T9N, R13W, SM 11. Present well condition, summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11,000' feet Plugs (measured) 9,775' feet 5. Datum elevation (DF or KB) RT 99' MSL 6. Unit or Property name TBU 7. Well number G-6rdL 8. Permit number 82-33 9. APl number 50-- 733-20073-01 10. Pool feet 10,870' feet Junk (measured) 9,632 feet Length Size Cemented 356' 26" Driven 631' 16" 1450 sx 3036' 13 3/8" 1250 sx 9,895' 9 5/8" 2200 sx 2,491' 7" 600 sx measured McArthur River Fie RECEIVED Alaska 0il & Gas Cons, Commbsior~ tr. ue vertical Anchorage Measured depth True Vertical depth 356' 356' 631 ' 631 ' 3036' 28Y9' 9,895 8672 ' 8,509-11,000' 7,374'-9 763' 9950,-9970'; 10,030!-10,045'; 10,075'-10,105'; 10,175'-i0,195'; 10,370'-10,400'; 10,421'-10,441' 8727'-8747': 8806'-8821'; 8851'-8880'; 8949'-8969'; 9141'-9171' TUbing (size, grade and measured depth) 3 1/2", 9.2# N-80 $ 10,280' Baker A-5 8430'-8442'; Baker F-1 ~ 10,292' Otis sssv ~ 293 Packers and SSSV (type and measured depth) .12.Attachments Description summary of proposal ~: Detailed operations program ~ BOP sketch 13. EStimated date for commencing operation " 5-0i-88 14. If proposal was verbally approved S:.: !;::.::: ; ~ ::":;:' .:.e?o:d:,.~,a ~.~: Name of approver Date approved 15. I hereby certify that,fJ~ foregoing is(to,¢ anCcc~r_r_ec/cto the best of my knowledge Signed~p_.~ ~Roy D. RdBeSts Title Environmental Spec. Commission Use Only Date 04/28/88 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved CopY R__.eturned .-~ Form 10-403 Rev 12-1-85 Commissioner I Approva, No. ~ ~' ,~,¢.~ .d the commission Date Sub~i{~/triplicate G-6rdL PERFORATION PROCEDURE 1. Rig up E-Line Unit. Pressure test lubricator to 2500 psi. 2. RIH with 2 1/8" perforating guns, 4 SPF, 0° phasing. Perforate · underbalanced or flowing as follows: ~-~ ~~ ~o,-~o ~oo, o~ B-4 ~~10,562'-10,~80' DIE (new) B-5 ~10,700'-10,815' DIL (new) B-6 (10,840'-10,884' DIL (new) 3. Rig down E-Line Unit. 4. Flow well to test separator. .... wE'LL TBus 'G-61 D CASING & ABANDONMENT DETAIL J ~ I.) Kelly Bushing at 0.00' ~ --E- ~ I1.) Dual Tubing Hanger at 33.60' , ~ ~ [ III.) 16', 75+, J-55 Casing at 631' · ~ ~ ' IV.) 13 3/8' 61~ J-55 Casing at 3036' I ---- ~ V.) Top 7', 29+, N-80 Liner at 8509 fyi I VI.) Window at 8917' to 8977° with KOP at 8917' C GLh'"-~' GL-"~- - VII.) 9 5/8", 47~, N-80 Casing Plugged Back ._ -- I at 8922' VIii.) Bottom 7', 29¢-, N.80 Liner at 11,000' '" ETAIL '. TUBING D ~ OL---'~ IC,~.F._. ~ LONG STRING: 3 1/2", 9.2¢f, N'80 TUBING ~ t ~ 1.) Otis 'XEL" Nipple at 292.65' .E GLt?._~I IGL"-"~' ~5 ! 2.) McMurray 'MN" Gas Lift Mandrel at 2007.54' F'--' i 3.) McMurray 'MN' Gas Lift Mandrel at 3387.54' --. i 4.) McMurray 'MN' Gas Lift Mandrel at 4668.54' IF GL___.~M ~ .6 5,) McMUrray 'MN.' Gas Lift Mandrel. at 5694.54' 6.) McMurray 'MN' Gas Lift Mandrel at 6780.54' L__._ 7.) McMuray 'MN' Gas Lift Mandrel at 7658.45' ! -, 8.) McMurray 'MN' Gas Lif~ Mandrel at 8359.52' ! !OL,...~I 7 9.) Otis 'XA' Sleeve at 8395.78' ' ! 10.) Baker Model 'A-5' Packer' .from 8429.52' ~ to.8442.26' O' GL.~.~ OL?.__~ .8 11.) Blast Joints from 9947.47~ to 10,006.45' 12.) Blast Joints fr'om 10,037.08' to 10,135.35' r4 x--~- 9 . 13.) Blast Joints .from 10,165.53' to 10,224.52' ' 14 Otis 'XA' Sleeve at 10,254.37' ~ ~o 1511 Locator Sub at 10,291.94' i 16.) Baker Model 'F-I' Packer with Seal Assembly ! from 10,292.44' ~o 10,308.33'. Packer at I 10,292'(DPM) i 17.) Bottom ;.Wireline Entry Guide at 10,309.00' v _, __I SHORT STRING: 2 7/8", 6.4,¢, N-80 TUBING A.) Otis 'XEL" Nipple at 297.11',, , B.) Camco-'KBMG' Gas Lift Mandrel at 2009.00' v, '. C.) Camco 'KBMG' Gas Lift Mandrel at 344.~:~0~'.~?' VII l' j D.) Camco 'KBMG' Gas Lift Mandrel at E.) Camco 'KBMG' Gas Lift Mandrel at 5963.00 _ 11 F.) Camco 'KBMG' Gas Lift Mandrel at 7142.00' G.) Camco 'KBMG' Gas Lift Ma(~,drel at -- ; H.) Otis 'XA" Sleeve at 8408.4 ~--- ~2 1.) Baker Model 'A-5' Packer from 8429.52' { to 8442.26' ' -- ! J.) Bottom of Otis 'XN' Nipple at 84 7.00 PERFORATION RECORD x~ l ~ DATE INTERVAL CONDITION · -4-5 5/09/82 9950'-9970' G-2 Production ~ ~-1"></16 10030'-10045' G-3 Production ~-------=~ t~ ~---.~. 10075'-10105' G-4 Production ~ 17 10175'-10195' G-5 Production 9/83 ° 10,370'- 10,400" HB~.I Production- 9/83. o 10421'-10441' HBO. 2 Production _.._. i i NOTE:'SUBTRACT 2~ FROM DIL TO GET CBL DEPTHS I VIll ~ ..... REV. I DAT[ .... I WELL. SCHEMATIC ,i ' UNION OIL COMPANY OF C.A, LIFOP,'Ni',~." ( STATE OF ALASKA ~' ALASKA OiL AND GAS CONSERVATION COw, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~r. OTHER 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 82-33 3. Address 8. APl Number P. O. Box 6247, Anchorage, Alaska 99502 50- 733-20073-01 4. Location of Well Cond. #46, Leg fl2, 1879' N, 1383' W of SE corner cf Sec. 29, TgN, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' above MSL 6. Lease Designation and Serial No. ADL 18730 9. Unit or Lease Name Trading Bay Unit 10. Well Number G-6 RD 11. Field and Pool McArthur River Field 12. , Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to perforate the following intervals: 10,370' - 10,400' (existing) 10,421' - 10,441' DIL (10,419' - 10,439' CBL) Subsequent l'¢ork 14. I hereby~ foregoing is true and correct to the best of my knowledge. Signed ~ Title Dist.-icL ... The space below fol~,COr~lrnis.~i,o~n~u~se Conditions of ApprOVal,' i'f'an~?'~''' Date Sept 15,-1 ' Approved by .... OR1G!NAI. SIGNED BY LONHIE C. SMITH COMMISSIONER ~,pproved Copy Returned By Order of the Commission 983 Form 10.403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Per~Fl~t_[~ UNION OIL CONPANY OF CALIFORNIA 3. Address P. 0. Box 6247, Anchorage, Alaska 99502 4. Location of Well Cond. #46, Leg #2, 1879' N, 1:~8:~' ~1 of SE corner of Sec. 29, T9N, Ri:~W, 5.14. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' above MSL .6. Lease Desi~nationand Serial No. /~DL 187:~0 8. APl N~r~_~ 20073_01 50- 9. Unit or L,e.ase Na~ne /raozng ~ay Unit 10. Well Number 6-6 RD 11. Field and Pool OTHER 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The .following intervals were perforated on September 7, 1983: 10,370' - 10,400' (existing) 10,421' - 10,441' DIL (10,419' - 10,439' CBL) *Verbal approval was received from Russ Douglas on September 2, 1983. 14. I hereby c,~e~ foregoing is true and correct to the best of my knowledge. Signed ( V_~_~J/'~ _~~-~"~-~ ~. Title Distr~ct Fno~n~er The space below _~r= C?~.__m'_~_' ._~,_, se Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date FOrm 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET A PAGE NO. LEASE Trading Bay Unit WELL NO. G-6 RD FIELD McArthur RiverField LOCATION: Conductor #46, ~eg #2, 1879'N & 1383'W of SE corner~ Section 29~ TgN~ R13W, SM. (surface location) PERMIT NO. 82-33 SERIAL NO. ADL 18730 SPUD DATE 4/2/82 COMP. DATE 5/19/82 CONTRACTOR Parker RIG NO. 54 TYRE UNIT 1320 National DRILL PIPE DESCRIPTION 5" iF ELEVATIONS: WATER DEPTH '125' RT TO OCEAN FLOOR 224' TD ll,O00'.MD TVD 9775' 'DEVIATION (BHL) BH anqle22°I'I"Ku~7110' COMPANY ENGINEER Graham, McAllister SIZE WEIGHT THREAD GRADE DEPTH 75# 0-55 16, REMARKS 631' 1450 sxs "G". cmt; last 300 sxs w/ ~% CaCL2 13 3/8" 61# 0-55 3036' 900 SXS "G" cmt w/ 10% gel & 2% CaCL2 /1000 Sxs "G" w/ 3% CaCL2 -9 5/8" 40/43.5/47 N-80/P-110 8917' 7" 29# Butt. N-80 11000' 3 1/2" 9.2#. Butt. N-80 . 9890' Top ~ 8509" cmt w/ 600 sxs "G"' cmt w/ 1% CFR-2~ 3% Halad 22A &.3% KCL. F~<r ~ 10280' MD 2 7/8" " " 8443' MD · PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION MD 9950-9970' 13 HPF 10030-10045' 13 HPF 5/9/82 10075-10105' 13 HPF 5/9/82 10175-10195' 13 HPF 10368-10398' 4 HPF INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 5/23/82 SS 16 74% 32 1140 80 107/64 LS 582 0.5% 32 ll40 140 " 422 725 WELL HEAD ASSEMBLY TYPE: CIW CASING HEAD: 12" 3M X 13 3/8" SOW CASING SPOOL: TUBING HEAD: 12" 3M x l~ 5M DCB TUBING HANGER: Duel 3 1/2" TUBING HEAD TOP: MASTER VALVES: CHRISTMAS TREE TOP CONN: UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 . WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DAILY COST: ACC COST: AFE AMT: 3/23/82 r 11429' TD Commenced operations over conductor 11381' ETD (CMT) #46 TBUS G-6 RD $ O0:O1 hrs 3/23/82. 9 5/8" C. 9895' Filled annulus & tbg w/ FIW. Pulled 7" L. 11429', Top $ 9750' ball valve. Attempted to open "XA" sleeve ~ 10469' - could not get $ 38,834 below 9679'. RU ARRS & perfed 7 $ 38,834 tiro holes in 3 1/2" tbg f/ 10465' to 10467'. Circ tbg & annulus w/ $3,076,000 FIW. Installed BPV. Removed tree. Installed & tested BOPE to 3000 psi. Pulled tbg out of pkr & oiro w/ FIW. Pulled & LD 309 its of 4 1/2" tbg & 27 jts of 3 1/2" tbg including 14 GLM's & seal assy. RIH w/ 8 1/2" bit on 9 5/8" csg scrpr while picking up 5" DP. 3/24/82 11429' TD Continued to PU 5" DP w/ bit & csg 9695' ETD (RET) scrpr. Tagged TOL ~ 9760' DPM. 9 5/8" C. 9895' Ciro& POOH. RIH & set ret ~ 9695' 7" L. 11429', Top $ 9750' DPM. RU & tested manifold to 6500 64 PCF 43 SEC psi. Broke down Hemlock parrs f/ DAILY COST: $ 27,935 ACC COST: $ 66,769 AFE AMT: $3,076,000 10630' to 11354' w/ 1800 psi. Pumped in w/ 20 CFM $ 3000 psi. Mixed & sqz'd w/ 350 sxs cl "G" w/ 3% KCL, .3% CFR-2, .1% Haled 22A. Displ 335 sxs below ret w/ e final rate of 12 CFM ~ 5600 psi. Sqz held 4000 psi w/ pumps off 10 min. CIP ~ 12:15 hrs. Rev out 15 sxs cmt, Press tested 9 5/8" csg to 3000 psi for 15 min - ok, POOH, RIH w/ 2' perf gun on APRS - had misfire, RIH w/ 2nd gun & perfed BS holes f/ 9001 to 9003', POOH, RIH w/ ret on WL - had misfire while trying to set, POOH, UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3 3/25/82 DAILY COST: ACC COST: AFE AMT: 4 3/26/82 11429' TD 8825' ETD (RET) 9 5/8" C. 9895' 7" L. 11429, Top ~ 9750' 64 PCF 43 SEC $ 53,018 $ 119,787 $3,076,000 11429' TD 9654' TD (JUNK) 9 5/8" C. 9895' 7" L. 11429', Top ~ 9750' 64 PCF 300 SEC DAILY COST: $ 44,165 ACC COST: $ 163,952 AFE AMT: $3,076,000 5 3/27/82 DAILY COST: ACC COST: AFE AMT: 11429' TD 9654' ETD (JUNK) 9 5/8" C. 9895' 7" L. 11429', Top ~ 9750' 64 PCF i70 SEC $ 28,101 $ 192,053 $3,076,000 RIH & set ret ~ 8950' WLM. RD APRS. RIH w/ Stinger on DP & tagged ret ~ 8936' DPM. Tested surf lines to 6500 psi.' PUmped into perfs w/ 15 CFM ~ 4200 psi. Form held 1250 psi w/pumps off lO.min. ~Mixed & sqz'd w/ 150 sxs cl "G" w/ 3% KCL, .3% CFR-2, & .3% Halad 22A for BS #2. Displ 145 sxs below ret w/ a final rate of 12 CFM ~ 5600 psi. Sqz held 4100 psi w/ pumps off 10 min. CIP ~ 06:55 hrs. Rev out 5 sxs cmt. POOH. Perfed 4 HPF f/ 8921' to 8923': WLM. RD APRS.~ RIH w/ ret on DP & set ~ 8825' DPM. Tested surf lines to 6500 psi. Broke down perfs w/ 4400 psi. Mixed & sqz'd w/ 150 sxs el "G" w/ 3% KCL, .3% CFR-2, .3% Halad 22A 'for BS #3. Displ 140 sxs below ret w/ a final rate of 15 CFM ~ 5500 psi. Sqz held 3900 psi w/ pumps off 10 min. CIP ~ 16:05 hrs. Rev out 10 sxs cmt.~ POOH. RIH w/ bit #1 on BHA #1. WOC, w/ bit ~8790'. RIH & tagged cmt ~ 8812'. Co contam cmt to top of ret 8 8825'. Brld ret 8 8825' & CO'firm cmt to top of ret ~ 8936'. Drld on ret ~ 8936'. POOH. Repair- ed rotary. RIH w/ bit #1RR #1 & drld ret ® 8937'. CO firm cmt to 9008'. RIH to 9654'. Ciro & POOH. POOH. RU APRS & Sperry Sun & ran gyro survey - tool stopped ~ 3810'. POOH. Removed springs and reran - would not go. POOH. RIH w/ 8 1/2" bit to 9654' &circ out visc mud. Changed hole over to FIW. RU ARRS & Sperry Sun. Ran gyro survey to 9600'. POOH. RIH w/ Servco sec- tion mill & began cutting section in 9 5/8" csg ~ 8917'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6 3/28/82 DAILY COST: ACC COST: AFE AMT:" 7 3/29/82 11429' TD 9654' TO (JUNK) 9 5/8" C. 9895' 7" L. ii429', Top ~ 9750' 64 PCF 47 SEC $ 33,713 $ 225,766 $3,076,000 'Milled window in 9 5/8" Csg f/ 8917' to 8938'. Trip for mill. RIH w/ mill #2 & milled window f/ 8938' to 8945'. 11429' TD Circ & POOH. RIH w/ mill #3 & 9654' ETD (JUNK) milled section in 9 5/8" csg f/ 9 5/8" window f/ 8917-8962' 8945' to 8947'. POOH - cutters bro- 9 5/8" C. 9895' ken. RIH w/ mill #4 & milled sec- 7" L. 11429, Top ~ 9750' tion f/ 8947' to 8962'. 65 PCF 84 SEC DAILY.COST: $ 33,997 ACC COST: $ 259,763 AFE AMT: $3,076,000 8 3/30/82 11429' TD 9654' ETD (JUNK) 9 5/8" Window 8917-8977'. 9 5/8" C. 9895' 7" L. 11429', Top ~ 9750' 65 PCF 150 SEC DAILY COST: $ 35,725 ACC COST: $ 295,488 AFE AMT: $3,076,000 9 3/31/82 11429' TD 8732' ETD (CMT) 9 5/8" C. 8917' 65 PCF 54 SEC DAILY COST: ACC COST: AFE AMT: Continued to mill window in 9 5/8" csg f/ 8962' to 8970'. Circ & pulled into shoe. Had difficulty pulling out of hole due to birds nest of mill cuttings. Circ hi vis sweep to clean hole & POOH. RIH w/ section mill #5 & milled section in 9 5/8" csg f/ 8970' to 8977' (total window f/ 8917 to 8977'). POOH. RIH w/ OEDR. $ 30,307 $ 325,795 $3,076,000 RIH w/ OEDP to 9070'. C&C mud. Mixed & equalized in 150 sxs cl "G" w/ 3% NaCL, .75% CFR-2, & 10% sd. CIP ~ 05:00 hrs. Est TOC ~ 8671'. POOH & WOC. Replaced rotary table motor (burned area on armature) w/ new motor. RIH w/ 8 1/2" bit to tag TOC ~ 8732'. Could not turn rotary table. UNION OIL COMRANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 10 4/1/82 11429' TD 8922' ETD (CMT) 9 5/8" C. 8917' (Wind°w) 65 PCF 54 SEC DAILY COST: $ 30,684 ACC COST: $ 356,419 AFE AMT: 11 4/2/82 DAILY COST: ACC COST: AFE AMT: 12 4/3/82 $3,076,000 11429 ' TD 8977' ETD (CMT 9 5/8" .C. 8917 65 PCF 43 SEC $ 59,852 $ 416,271 $3,076,000 11429' TD 8775' ETD (CMT) 9 5/8" C. 8917' 65 PCF 43 SEC DAILY COST: $ 30,604 ACC COST: $ 446,875 AFE AMT: $3,076,000 13 4/4/82 8934' TD 9 5/8" C. 8917' 65 PCF 49 SEC DAILY COST: ACC COST: AFE AMT: 14 4/5/82 DAILY COST: ACC COST: AFE AMT: $ 46,798 $ 493,673 $3,076,000 8976'/42' 9 5/8" C. 8917' 66 PCF 48 SEC $ 50,638 $ 544,311 $3,076,000 CO.cmt f/ 8732' to 8922' (5' below top of window). C&C mud. POOH. RU SDC to run gyro to confirm Sperry Sun gyro ran on 3/28/82 (Note: +~00' difference in Sperry gyro vs old hole magnetic surveys). Completed running SOO gyro survey f/ 8922' to surf. SDC gyro agreed w/ Sperry Sun gyro. RIH w/ bit #4 on BHA #1.for Qyna drl run #1. Oreinted tool 130° left of high side. Dyna drld 8 1/2" hole f/ 8922 to 8977' - hit 9 5/8" csg stub ~ 8977'. POOH w/ dyna. drl. RIH w/ OEDP to 8976'. Mixed & equalized in 75 sxs cl "G" w/ 3% NaCL, .75% CFR-2, & 10% sd. POOH. RIH w/ blt #3 RR #1 on BHA #2 for clean out run to 7500'. WOC. RIH & tagged cmt ~ 8722'. CO firm cmt f/ 8722' to 8775'. Cont to CO.cmt f/ 8775 to 8875'. WOC. CO hrd cmt f/ 8875' to 8922'. Circ& POOH. RIH w/ bit #5 on BHA #3 for Dyne drl run #2. RU Sperry Sun & oriented tool 130° left of high side. Dyne drld 8 1/2" hole f/ 8922' to 8934' (drld 1st 5' ~ 1 FPH & next 7' ~ 2 FPH). Trip for bit change. Trip for bit change. RIH w/ bit #6 on BHA #3 for Dyna dr1 run #3. Dyna drld 8 1/2" hole f/ 8934' to 8945' - blew up rotary hose. Re- placed rotary hose. Could not pump thru dyna dr1. POOH -dyna dr1 had failed. RIH w/ bit #7 on BHA #4 for Dyne drl run #4. Oriented tool & dyne drld 8 1/2" hole f/ 8945' to 8976'. UNION OIL CONPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 4/6/82 9139'/163' 9 5/8" C. 8917' 66 PCF 65 SEC DAILY COST: $ 44,938 ACC COST: $ 589,249 AFE AMT: $3,076,000 16 4/7/82 9411'/272' 9 5/8" C. 8917' 68 PCF 56 SEC DAILY COST: ACC COST: AFE ANT: /8/82 DAILY COST: ACC COST: AFE AMT: 18 4/9/82 $ 47,805 $ 637,054 $3,076,000 9568'/157' 9 5/8" C. 8917' 68 PCF 61 SEC $ 40,139 $ 677,193 $3,076,000 9928'/360' 9 5/8" C. 8917' 69 PCF 62 SEC DAILY COST: $ 28,807 ACC COST: $ 706,000 AFE AMT: $3,076,000 19 4/10/82 10124'/196' 9 5/8" C. 8917' 68 PCF 60 SEC DAILY COST: $ 35,064 ACC COST: $ 741,064 AFE AMT: $3,076,000 20 4/11/82 10444'/320' 9 5/8" C. 8917' 69 PCF 72 SEC DAILY COST:. ACC COST: AFE AMT: $ 32,125 $ 773,189 $3,076,000 Dyna drld 8 1/2" hole f/ 8976' to 9020'. POOH & LD dyne-drl. RIH w/ bit.#8 on BHA #5 (30' pendulum) & -reamed dyne drl run f/ 8917' to 9020'. Dir drld 8 1/2" hole f/ 9020' to 9139'. Trip for bit chng. Survey: 9042" 23° S67 1/2OE RIH w/ bit #9 on BHA #5 (30' pendu- lum). Reamed f/ 9045' to 9139'. Dir drld 8 1/2" hole.f/ 9139' to 9411'. Circ & POOH. RIH w/ blt #10 on BHA #6 for Dyne drl run #5. SUrveys: 9228' 15° S67 1/2°E 9320' 12° S63 1/2°E Oriented dyne drl 60° left of HS & dyne drld 8 1/2" hole f/ 9411' to 9493'. POOH. RIH w/ bit #11 on BHA #7 (30' belly follow assembly) & reamed dyne drl run f/ 9411' to 9493'. Dir drld 8 1/2" hole f/ 9493 to 9568' POOH. RIH w/ bit #12 on BHA #8 (iocked up assy). Surveys: 9507' 14° S84°E Bit drld 8 1/2" hole f/ 9568' to 9928'. Surveys: 9605' 14° S87~1/2E 9788' 12° S85 1/2E Dir drld 8 1/2" hole f/ 9928' to 10078'. Circ & POOH. RIH w/ bit #13 on BHA #9 (30' belly) & reamed f/ 10028' to 10078'. Dir drld 8 1/2" hole f/ 10078' to 10124'. Surveys: 9915' 11° S85 1/2E 10018' 10° S85 1/2E Dir drld 8 1/2" hole f/ 10124' to 10444'. Circ & POOH. Had tight spots ~ lOll2', lO021', & 9990'. Surveys: 10160' 9° S85 1/2E 10280' 8 1/2° S81 1/25 10374' 7° S85E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS', DESCRIPTIONS & RESULTS 21 4/12/82 DAILY COST: ACC COST: AFE AMT: 10698'/254' 9 5/8" C. 8917' 70 PCF 68 SEC $ 35,965 $ 809,154 $3,076,000 Fin POOH. RIH w/ bit #14 on BHA #10 (60' belly)'& reamed f/ 10394' to 10444'. Dir drld 8:1/2" hole f/ 10444' to 10698' - had high torque. Circ & POOH. Surveys: 10504' 7° S85E 10643' 9° S85E 22 4/13/82 DAILY COST: ACC COST: 11000'/302' 9 5/8" C. 8917' 69 PCF 61 SEC $ 42,699 $ 851,853 RIH w/ bit #15 on BHA #10 & reamed f/ 10627 to 10698'. Dir drld 8 1/2" hole f/ 10698' to 11000'. Circ & made short trip to shoe ~ 8917' - trip was smooth. Wait 1 hr. AFE AMT: $3,076,000 23 4/14/82 DAILY COST: ACC COST: AFE AMT: 11000' TD 9 5/8" C. 8917' 69 PCF 56 SEC $ 78,101 $ 929,954 $3,076,000 RIH to 11000' after short trip. C&C hole for logs. POOH. RU Schlumberger. Ran DIL-Sonic log f/ 11000' to~8917'. Ran FDC-CNL log f/ 11000' to 2500'. 24 4/15/82 DAILY COST: ACC COST: 11000'/0' 13 3/8" C. 3036' 9 5/8" C. 8917' 69 PCF 53 SEC $ 148,798 $1,078,752 Completed FDC-CNL log. RIH w/ bit #4 RR #1 on BHA #10. Reamed f/ 10952' to btm ~ 11000'. C&C hole for liner. POOH. Ran 7" 29# N-80 butt liner. Reciprocate liner while C&C mud prior to cmtg. AFE AMT: $3,076,000 25 4/16/82 11000' TD 8509' ETD (Cmt in TOL) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' 69 PCF 58 SEC DAILY COST: $ 42,493 ACC COST: $1,121,245 AFE AMT: $3,076,000 Liner Detail: Cont to reciprocate liner while C&C mud. Tested lines to 3700 psi. Pumped 18 bbls of caustic water & 5 bbls of fresh water ahead of 600 sxs cl "G" w/ 1% CFR-2, .3% Halad 22A, & 3% kc1. Displ w/ 10 bbls fresh wa- ter & 232 bbls of mud to bump plug on ldg collar ~ 10870' w/ 3000 psi. Released press & floats held ok. CIP ~ 05:50 hrs. Released f/ hanger & POOH w/ DP. LD 5" HWDP. RIH w/ 8 1/2" bit on 3-6 1/4" DC's & 5" DP to 7500'. WOC for a total of 12 hrs. RIH & tagged cmt ~ 8219' (290' above TOL). Drld out firm cmt f/ 8219' to TOL ~ 8509'. Circ & POOH. BOT Shoe ~ llO00' BOT FC ~ 10955' BOT LC ~ 10870' BOT hanger ~ 8519' Top of tie-back ~ 8509' Total liner - 57 jts of 7" 29# N-80 buttress 2490.57 OA. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 26 4/17/82 DAILY COST: ACC COST: AFE AMT: 27 4/18/82 DAILY COST: ACC COST: AFE AMT: 28 4/19/82 DAILY COST: ACC COST: AFE AMT: 29 4/20/82 DAILY COST: ACC COST: AFE AMT: llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000, Top ~ 8509' 69 PCF 58 SEC $ 23,661 $1,144,906 $3,076,000 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW $ 63,102 $1,208,008 $3,076,000 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW $ 35,716 $1,243,724 $3,076,000 llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top '8509' FIW $ 175,892 $1,419,616 $3,076,000 Fin LB excesS 5" DP. RIH w/ 6" bit on 4 3/4" DC's & 3 1/2" DR stinger - drld 21' of cmt in TOL f/ 8509' to 8530'. RIH & CO cmt'f/ 10800' to 10870'. Circ & tested liner & lap .to 3000 psi - ok. POOH. RIH w/ 8 1/2" bit & 9 5/8" csg scrpr to 8509'. Circ & POOH. RU Sperry Sun gyro on. ARRS WL. RIH - gyro would not go into TOL. POOH to chng cen- tralizers. Changed:centralizers &'RIH w/ gyro - tool would not work. POOH & chngd tools. RIH & ran gyro f/ 10800' to to 8500'. POOH & RD WL. RIH w/ RTTS & hydro-spring on dry DP. Set RTTS ~ 8407'. Opened hydro-spring valve & dry tested liner & lap 1 hr. Had light bloW 15 min then dead. Released RTTS & POOH. RU Schlum & ran CBL-VDL-GR log f/ 10850' to 7800'. RD Schlum. RIH w/ 6" bit & 7" csg sorpr to 10870'. Circ & changed hole over to FIW. POOH. Completed POOH. RIH w/ 8 1/2" bit & tagged liner top for tie-in ~ CBL. , DP found liner top ~9!7', ~06-' ~$/7~ ~S~ DIL. POOH. Made up & RIH w/ 5" Geo-Vann guns on DP. Located guns across "G"-zone as follows: G-2 f/ 9950' to 9970' DIL, G-3 f/ 10030' to 10045' DIL, G-4 f/ 10075' to lOl05' DIL, & G-5 f/ 10175' to 10195' DIL. RU DA & ran gamma ray log in DR for correlation. RD DA. RU BO & displ DR w/ N2. Displ DP w/ N2 to 8288' TVD. Set RTTS ~ 9841'. Bled N2 press to 1500 psi on surf & dropped firing head. Parred "G"-zone w/ 9 HPF. Rev out oil & FIW to prod header after well died. Gao Vann guns fired ok. RIH w/ 6" bit & csg scrpr to 10500'. POOH. RIH w/ GR & OB to 10400'. POOH. RIH w/ 7" model F-1 Baker pkr on WL. Set pkr ~ 10280' DIL. RIH w/ seal assy on DP. Stab into & test pkr to 500 psi. POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 30 4/21/82 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000-8509' FIW DAILY COST: $ 21,505 ACC COST: $1,441,121 AFE AMT: $3,076,000 31 4/22/82 DAILY COST: ACC COST: AFE AMT: 32 4/23/82 DAILY COST: ACC COST: AFE AMT: 33 4/24/82 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000-8509' FIW $ 107,635 $1,548,756 $3,076,000 llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 8509 to 11000' FIW $ 262,004 $1,810,760 $3,076,000 llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW DAILY COST: $ 25,355 ACC COST: $1,836,115 AFE AMT: $3,076,000 34 4/25/82 DAILY COST: ACC COST: 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top 8509' FIW $ 24,594 $1,860,709 .LD DP, Changed pipe rams. Completed running dual 3 1/2" X 2 7/8" completion assembly. Test down annulus to confirm stabbed into model "F" pkr ~ 10280'. Spaced out & landed Tbg, Ru Meyers WL. Pulled ball valve dummy & set "XN" plug in SS ® 8439'. Press up on SS w/ 1500 psi to set dual "A-5" pkr. Retrieved "XN" plug. Tested "A-5" pkr w/ 500 psi down SS - ok. In- stalled BRV's & removed BORE. In- stalled tree & tested to 5000 psi - ok. Retrieved ball valve dummy in LS. Dropped ball in LS to shear out guide shoe. Installed flowlines. Began to gas lift well thru LS. Cont to gas lift well - LS would not lift after 143 bbls produced. Gas lift valves were not set correctly, RU Myers WL, Bled off tbg, Pulled GLV's f/ LS & sent valves to Otis for readjustment. Pulled GLV's in SS, Replaced readjusted GLV's in LS & SS. Began to gas lift both strings to clean up. AFE AMT: $3,076,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, 'DESCRIPTIONS & RESULTS 35 4/26/82 DAILY COST: ACC COST: AFE AMT: 36 4/27/82 11000 ' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top $ 8509' FIW $ 24,255 $1,884,964 $3,076,000 11000' TD 10870'-ETD (LC) 9 5/8" C. 8917' 7" L 11000' Top ¢ 8509' · , FIW DAILY COST: $ 34,276 ACC COST: $1,919,240 AFE AMT: $3,076,000 37 4/28/82 DAILY COST: ACC COST: AFE AMT: 38 4/29/82 DAILY COST: ACC COST: AFE AMT: 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW $ 34,925 $1,954,165 $3,076,000 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000-8509' FIW $ 41,475 $1,995,640 $3,076,000 Attempted to gas lift well. RU Myers WL & tagged fluid level in LS ~ 8412' WLM. POOH. Tagged fluid level in SS ~ 3410' WLM. POOH. Attempted to gas lift well-unable to lift SS. RIH & tagged fluid level in SS ~ 3528'. POOH. RIH & retrieved GLV f/ GLM ~ 4652'. RIH & replaced GLV w/ new valve. Attempted to gas lift SS - produced 6 bbls in 4 hrs. RU Myers WL. RIH in SS & retrieved 4 GLV's (#1, 3, 4, 5 - from top). Had valves read- justed & replaced same. Attempted to GL SS - produced a total of 92 bbls of FIW in 8 1/2 hr. RIH in SS w/ sinker bars to check FL in SS - found FL $ 8350'. Ran , sinker bars 10 out of tail to con- firm open. POOH. Opened "XA" in SS ~ 8371' & in LS ~ 8378' Pumped FIW down LS & up ann, then ~S until full. Closed "XA" sleeve in LS ~ 8378'. Press tested LS to 1500 psi- ok. Opened "XA" sleeve in LS ~ 10289' & closed "XA" in SS ~ 8371'. Circ down LS & up SS - rec some oil. Spotted diesel & 10% U-66 (surfac- tent) as follows: 42 bbls of diesel U-66 blend, 17 bbls of blend w/ 40# of unibeads, 30 bbls of blend, 9 bbls of blend w/ unibeads. Closed XA in LS ® 10289' & began injecting diesel blend as follows: 9 bbls of blend w/ unibeads, 20 bbls of blend, 17 bbls of blend w/ 40# of unibeads, 40 bbls of blend, 50 bbls of FIW. Injected a total blend of 135 bbls thru the perfs w/ a final rate of 1 BRM ~ 4000 psi. Diesel blend in place e 08:00 hrs.. Shut well in to soak. Began lifting LS e 14:00 hrs. Lifted 140 bbls of fluid when it quit lifting. Began attempting to lift SS ~ 20:00 hrs. SS would not lift. Bled off gas press to 275 psi. Opened XA sleeve in SS ® 8371' to equalize fluid. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. lO LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 39 4130/82 DAILY COST: ACC COST: AFE AMT: 40 5/1/82 DAILY COST: ACC COST: AFE AMT: 41 5/2/82 DAILY COST: ACC COST: AFE AMT: 42 5/3/82 - j 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L.' 11000', Top ~ 8509' FIW $ 24,805 $2,020,445 $3,076,000 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW $ 24,525 $2,044,970 $3,076,000 llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW $ 39,298 $2,084,268 $3,076,000 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW DAILY COST: $ 35,759 ACC COST: $2,120,027 AFE AMT: $3,076,000 43 5/4/82 DAILY COST: ACC COST: AFE AMT: llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW $ 24,043 $2,144,070 $3,076,000 Equalized fluid between SS & ann by putting 300 psi on SS. Closed XA sleeve in SS $ 8371'. Attempted to GL SS - would not lift. Tied well G-14A (gas well) into ann of G-6 RD. Be- gan to gas lift G-6 RD w/ 1550 psi gas press. Had to alternate between LS & SS to 11ft fluld. Cont to GL both strings. Lifted a total of 483 bblsof FIW when both strings began.to cYcle gas. RU Myers WL on SS & tagged fluid level $ 7600' (#5 GLM). POOH. BLed gas press off of well. Opened XA sleeve in SS ® 8371' & XAsleeve in LS ~ 10289'. POOH, Filled well w/ FIW. Circ down LS & up both SS & ann to kill well. Installed BRV's & re- moved tree. Installed BORE. Completed inStalling & testing BOPE to 3000 psi - ok. RU & attempted to pull pkr loose w/ 220M# (±7OM# over pull) - pkr would not pull loose. Rehung tbg. RU DA on SS - attempted to cut ~ 8390'. Charge did not fire. Made 2nd run & cut SS ~ 8410' WLM (7' above pkr). RIH in LS & cut ~ 8586' (4' below XA sleeve). ROOH w/ WL. RU & began to pull tbg. Comp LD dual comp tbg. Changed pipe rams. RIH w/ 8 1/8" OS w/ 3 1/2" grapple, 7" X 3 1/2" hollow mill control, bumper sub & oil jars while RU 3 1/2" DR. Fin RIH w/ fishing tools on 3 1/2" DP. Milled over & latched onto top of fish ~ 8386'. Pulled 64M# over RU & pkr came loose. POOH & LD dual A-5 pkr & remainder of 3 1/2" tbg string. RIH w/ seal assy on 3 1/2" & 5" DR to stab into pkr ~ 10280'. Tested pkr - ok. POOH. RIH w/ Howco 7" RBR & attempted to set RBR ~ 10260' - plug would not set. POOH - left RBR in hole. RIH to locate RBR. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. ll LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 44 5/5/82 DAILY COST: ACC COST: AFE AMT: 45 5/6/82 DAILY COST': ACC COST: AFE AMT: 45 5/7/82 11000' TD 10870' ETD (LC) · 9 5/8" C. 8917' 7" L. llO00', Top ~ 8509' FIW $ 32,026 $2,176,096 $3,076,000 llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000', Top ~ 8509' FIW $ 37,246 $2,213,342 $3,076,000 llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000-8509' 65 PCF BRINE DAILY COST.: $ 46,799 ACC COST: $2,260,141 AFE AMT: $3,076,000 47 5/8/82 DAILY COST: ACC COST: llO00' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000-8509' 65 PCF BRINE $ 24,200 $2,284,341 RIH & located RBP $ 10'268' DIL (8' below attempted setting pt). Hung OEDR ® 10248'& pumped 8 sxs sd. Wait 2 hrs & tagged top of sd e 10233' DIL. Circ & changed hole over to 6% KCL'in FIW. POOH. Chgd rams.. RU & ran single 3 1/2" test assy w/ single hyd pkr. Comp running single 3 1/2" test string w/ tail ~ 9890'. Set "x" plug in nipple & set single hyd pkr w/ 1550psi. Removed "x" nipple & tested pkr to 600 psi - ok. Removed BORE. Installed & tested tree to 5000 psi - ok. RU'DA & tested lub to 3000 psi - ok. RIH w/ GR/ampli- field ccl log to locate previously shot perfs. Log indicated perfs were shot correctly. POOH & RD DA. Began to GL well. Gas lifted well' Stopped lifting after +315 bbls lifted. Tagged FL w/ WL ~ 3880'. Changed GLV's $ 2208 & 4656'. Lifted well. Ran surf readout press temp survey. Lifted well varying tbg press to operate GLV's. AFE AMT: $3,076,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 12 LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS,:DESCRIPTIONS & RESULTS 48 5/9/82 DAILY COST: ACC COST: AFE AMT: - 49 5/10/82 DAILY COST: ACC COST: AFE AMT: 50 5/11/82 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 11000-8509' 65 PCF BRINE $ 87,500 $2,371,841 $3,076,000 11000' TD 10233' 'ETD' (RBR) 9 5/8" C. 8917' 7" 1. 11000-8509' $ 101,978 $2,473,819 $3,076,000 11000' TD 10233' ETD (RBP) 9 5/8" C. 8917' 7" L. 11000-8509' DAILY COST: $ 53,265 ACC COST: $2,527,084 AFE AMT: $3,076,000 51 5/12/82 DAILY COST: ACC COST: AFE AMT: 11000' TD 10233' ETD (RBP) 9 5/8" C. 8917' 7" L. 8509-11000' 64 PCF BRINE $ 64,073 $2,591,157 $3,076,000 Perfed G-5 f/ 10175 to.10195' & G-4 f/ 10075 to 10105' w/ DA 2 5/8" cased carriers on 600 psi drawdown. GL well. Had slight entry of oil. Perfed G-3 f/ 10030' to 10045' & G-2 fl 9950' to 9970'~ Lifted well - small entry. Cont GL well. Rate incr. Avg'd f/ 160 to 240 BFPD w/ 5 to 10% cut. RU Dowell. Pumped 80 bbls 7.5% HCL w/ .5% A200, ~4% W35 & .3% F75N follow- ed by 4 100 bbl stages of 12-6 mud acid w/ 1%~A200, .8% W35 & .3% F75N diverted w/ 56# 0S90 in 3% NH4CL. Pumped as follows: 1st 50 bbls to fill tbg, f/ 50 to 110 bbls pumped ~ 2 BPM w/ 3000 psi, f/ 110 to 350 bbls pumped ~ 2 BPM w/ 500 to 1500 psi. Discovered comm w/ ann after 350 bbls pumped. Press on ann w/ water. Pumped remainder of acid ® 2 BPM w/ 1500 to 2200 psi. Displ acid to perfs w/ N2. Displ acid w./ N2. Opened "XA" sleeve ~ 8126' 'w/ WL. Displ ann w/ N2. Put well on gas lift. Rec 171 bbls total ann fluid & well stopped lifting. Closed sleeve ~ 8126'. Tagged FL ~ +6900'. Ran surf read- out press &temp survey. Valve ~ 6784' not working. Put gas well on ann for more press. GL well until rec all ann fluid. Bottom hole flowing press ® "G"-zone perfs 1200 psi i.e. 1700 psi draw- down w/ no entry. (Note: had gas grad to tbg tail i.e. pkr had failed). Bled off ann gas. Spot 50 bbl pill of 6% KCL, 25 RRB safe- seal & i RRB "XC" to perfs. Filled tbg & ann w/ 6% KCL fluid. In- stalled'BRV's. Removed tree. In- stalled BORE. Rulled pkr loose. Hole taking fluid ~ 40 bbls/hr. Dropped down to 10182' w/ tbg. Spot 50 bbl safe-seal pill across perfs (30 RRB safe-seal & 2 RRB "XC" in 6% KCL fluid). Well still taking fluid ~ +20 bbls/hr. UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE ADL 18730 WELL NO. G-6 RD SHEET D PAGE NO. 13 FIELD McArthur River Field DATE ETD DETAILSOF OPERATIONS, DESCRIPTIONS & RESULTS 52 5/13/82 DAILY COST: ACC COST: AFE AMT: 53 5/14/82 DAILY COST: ACC COST: AFE AMT: 54 5/15/82 11000' TD 10250' ETD 9 5/8" C. 8917' 7" L. 8509-11000' 65 PCF BRINE $ 35,515 $2,625,672 $3,076,000 11000' TD 10870''ETD (LC) 9 5/8" C. 8917' 7" L. 8509-11000' 65 PCF BRINE $ 25,809 $2,651,481 $3,076,000 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 8509-11000' 65 PCF BRINE DAILY COST: $ 25,809 ACC COST: $2,651,481 AFE AMT': $3,076,000 55 5/16/82 11000 ' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 8509-11000' DAILY COST: $ 52,898 ACC COST: $2,704,379 AFE AMT: $3,076,000 56 5/17/82 DAILY COST: ACC COST: 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 8509-11000' $ 87,175 $2,813,494 (corr) Spot 50 bbl pill'of 2 PPB "XC", 50 PPB safe-seal in 6% KCL fluid across "G" perfs - slowed loss circ to +10 bbls/hr. Spot 50 bbl pill same as before across "G" zone .perfs - loss circ 3 bbl/hr. Pulled & layed down 3 1/2" tbg. CO w/ bit & scrpr to 10250'. NOte: had fill ~ 10202'. Spot 50 bbl pill across "G" perfs. POOH w/ tbg. Ran, 6"bit & 7" scrpr to' 10250' (had 49' of fill). POOH. RIH & retrieved BP f/ 10250' & POOH. Ran 400' of 2 3/8" tbg on seal assy & DP. RIH to 10680'. Tested pkr ~ 10280'. POOH LD DP. Ran dual 2 7/8" & 3 1/2" comp assy. Stabbed LS into pkr ~ 10280'. LS would not test. Set plug on WL in "XA" above "A-5" dual & tested LS - ok. Retested LS - ok. Set dual "A-5" ~ 8443'. Slacked off 2' & landed tbg on hanger after setting pkr. Tested "A-5" pkr - ok. Knocked bullnose .out of LS w/ sinker bar. Installed BPV's, removed BOPE, installed & tested CIW tree, pulled BPV's. Put well on gas lift. GL well. Changed top GLV in SS. Put gas well on ann to incr csg. press. NOW: Lifting well (227 bbls rec). AFE AMT: $3,076,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE ADL 18730 WELL NO. G-6 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 57 5/18/82 DAILY COST: ACC COST: AFE AMT: 58 5/19/82 DAILY COST: ACC COST: 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 8509-11000' $ 24,805 $2,838,299 $3,076,000 11000' TD 10870' ETD (LC) 9 5/8" C. 8917' 7" L. 8509-i1000' $ 30,122 $2,868,421 GL LS & SS'~ 02:00 hrs - total 688 bbl unloaded. LS cycling gas - SS still unloading ~ 984 BD. Gas inj ~ 1493 MCFD.® 1200 psi, 100 psi on tbg. Assumed LS unloaded. RU DA & RIH.& perf Hemlock f/ 10398' to 10383'. Wait i 1/2 hr - no flow. Rerf 10383-10368'. Wait 1/2 hr - no flow. RU & run tamp & press grad survey. Rress gradshowed fluid to surf. Tempgrad changed ® 8325' (btm GLV). Run CCL log.- perfs shot in correct spot. Run 2nd. press &temp grad survey. LS lifting f/ 3rd valve (4662') on lift. LS began producing 100% wtr. Released rig @12:00 hrs 5/19/82. Moved to G-2 RD. AFE AMT: $3,076,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE Trading Bay Unit WELL NO. TBUS G-6 RD FIELD SHEET D PAGE NO. McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7" LINER DETAIL JTS DESCRIPTION - LENGTH BTM TOP 10 10 22. 7" B.O.T. Float Shoe 7" 29# N-80 Butt Csg 7" B.O.T. Float Collar 7" 29# N-80 Butt Csg 7" B.O.T. La~ding Collar 7" 29# N-80 Butt Csg 7" Butt Pup (1) 7" 29# N-80 Butt Csg 7" Butt Pup (1) 7" 29# N-80 Butt Csg 7" Butt Pup (1) 7" 29# N-80 Butt Csg 7" Butt Pup (1) 7" 29# N-80 Butt Csg XO Cent. Bushing B.O.T. "Shorty" Hanger Seal Nipple Tie-Back Sleeve 1.85' 11000' 42.43' 10998.15' · 95' 10955.72" 84.18' 10954.77' · 95' 10870.59' 165.46' 10869.64' 24.84' 10704.18' 335.07' 10679.34' 22.72' 10344.27' 414.49' 10321.55' 23.36' 9907.06'' 410.33' 9883.70' 16.83' 9473.37' 933.21' 9456.54' 2.45' 8523.33' 2.00' 8520.88' 3.35' 8518.88' 6.10' 8515.53' 10998.15' 10955.72' 10954.77' 10870.59' 10869.64' 10704.18' 10679.34' 10344.27' 10321.55' 9907.06' 9883.70' 9473.37' 9456.54' 8523.33' 8520.88' 8518.88' 8515.53' 8509.43' Form D-IOO1-B LEASE Tradinq Bay. Unit COMPLETION DATE 5/19/82 UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET 8 RAGE NO. I WELL NO. TBUS G-6 RD FIELD McArthur River Field APPROVED DATE E.T.D. JTS DESCRIPTION DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS TUBING DETAIL - LONG STRING . LENGTH BTM TOP 49 3 1/2" Wireline Entry Guide 80-40 Seal Assembly 7" Baker Model F-1 Rkr ® 10280' DIL, 10292' DRM Locator 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Otis "XA" Sleeve 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Blast Joints 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Blast Joints 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Blast Joints 3 1/2" 9.2# N-80 Butt Tbg 9 5/8" x 3 1/2" x 3 1/2" 51-B "A-5" Rkr 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Otis "XA" Sleeve 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurray MN 1.O GLM WELL HEAD ASSEMBLY TYPE: CASING HEAD: CASING HANGER: CASING SPOOL: TUBING HEAD: TUBING HANGER: TUBING HEAD TOP: MASTER VALVES: · 67' 10309.00' 10308.33' 15.89' 10308.33' 10292.44' .50' 4.00' 29.69 ' 3.88' 29.85' 58.99' 30.18' 98.27' 30.63' 58.98' 1505.21' 12.74' 29.76' 3.98' 30.05 ' 6.21' 10292.44' 10291.94' 10291.94' 10287.94' 10287.94' 10258.25' 10258.25' 10254.37' 10254.37' 10224.52' 10224.52' 10165.53' 10165.53' 10135.35' 10135.35' 10037.08' 10037.08' 10006.45' 10006.45' 9947.47' 9947.47' 8442.26' 8442.26' 8429.52' 8429.52' 8399.76' 8399.76' 8395.78' 8395.78' 8365.73' 8365.73' 8359.52' CHRISTMAS TREE TOP CONN.: Form D-lOO1-B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO. 2 LEASE Trading Bay Unit COMPLETION DATE 5/19/82 WELL NO. TBUS G-6 RD FIELD McArthur River Field APPROVED DATE E.T.D. STS 23 29 36 34 42 45 57 DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS TUBING DETAIL - LONG STRING (cont.) _ DESCRIPTION 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurray MN 1.0 GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurray MN 1.O GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurray MN 1.O GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurray MN 1.O GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurray MN 1.O GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" MoMurray MN 1.O GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Otis "XEL" Landing Nipple 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Tubing Hanger Landed Below KB LENGTH BTM TOP 694.87' 8359.52' 7664.65' 6.20' 7664.65' 7658.45' 871.70' 6.21, 1079.80' 6.20' 1019.79' 6.21' 1278.80' 7658'45' 6786.75' 6786'75' 6780.54' 6780'54' 5700.74' 5700.74' 5694.54' 5694.54' 4674.75' 4674.75' '4668.54' 4668.54' 3389.74' 6.20' 3389.74' 3383.54' 1369.79' 3383.54' 2013.75' 6.21 ' 2013.75 ' 2007.54 ' 1712. O0 ' 2007.54 ' 295.54 ' 2.89' 295.54' 292.65' 258.05' 292'65' 34.60' 1.00' 34.60' 33.60' 33.60' 33.60' 0 WELL HEAD ASSEMBLY TYPE: CASING HEAD: CASING HANGER: CASING SPOOL: TUBING HEAD: TUBING HANGER: TUBING HEAD TOP: MASTER VALVES: CHRISTMAS TREE TOP CONN.: Form D-iOO1-B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO. 3 LEASE Trading Bay Unit COMPLETION DATE 5/19/82 WELL NO. TBUS G-6 RD FIELD APPROVED McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS JTS 1 39 37 39 DESCRIPTION 2 7/8" Otis "XN" Nipple 2 7/8" Butt Pup (1) TUBING DETAIL - SHORT STRING LENGTH 1.80' 9.60' 3 1/2" 10rd x 2 7/8" Butt xo 9 5/8" dual A-5 pkr Safety Sub 2 7/8" Butt x 3 1/2" 10rd xo 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Otis "XA" Sleeve 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Camco KBMG GLM 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Camco KBMG GLM 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Camco KBMG GLM 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Camco KBMG GLM .68' 10.00' .28' .71' 31.96' 3.57' 30.28 ' 6,12' 1223.87 ' 6.13' 1172.88 ' 6.12' 1240.80' · 6.20' BTM TOP 8467.00' 8465.20' 8465.20' 8455.60' 8455.60' 8454.92' 8454.92' 8444.92' 8444.92' 8444.64' 8444.64' 8443.93' 8443.93' 8411.97' 8411.97' 8408.40' 8408.40' 8378.12' 8378.12' 8372.00' 8372.00' 7148.13' 7148. O0 ' 7142. O0 ' 7142.00' 5969.12' 5969.12' 5963.00' 5963.00' 4722.20' 4722.20' 4716.00' WELL HEAD ASSEMBLY TYPE: CASING HEAD: CASING HANGER: CASING SPOOL: TUBING HEAD: TUBING HANGER: TUBING HEAD TOP: MASTER VALVES: CHRISTMAS TREE TOP CONN.: Form D-lOO1-B LEASE Trading Bay Unit COMPLETION DATE 5/19/82 UNION OIL CO. OF CALIFORNIA REPAIR RECORD WELL NO. TBUS G-6 RD FIELD APPROVED SHEET B PAGE NO. 4 McArthur River Field DATE E.T.D. JTS 4O 45 54 DETAILS OF ORERATIONS~ DESCRIPTIONS & RESULTS TUBING DETAIL - SHORT STRING (cont.) LENGTH BTM 1264.86' 4716.00' 6.14' 3451.14' 1429.87' 3445'00' 6.13' 2015.13' 1709.00' 2009..00' 2.89' 300.00' 262.51~ 297.11' 1'00' 34.60' 33~60' 33.60' DESCRIPTION 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Camco KBMG GLM 2 7/8" 6' 4# N-80 Butt Tbg 2 7/8" Camco KBMG GLM 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Otis "XEL" Landing Nipple 2 7/8" 6.4# N-80 Butt Tbg Dual Hanger Landed below KB TOP 3451.14' '3445.00' 2015.13' 2009.00' 300.00' 297.11' 34.60' 33.60' 0 WELL HEAD ASSEMBLY TYPE: CASING HEAD: CASING HANGER: CASING SPOOL: TUBING HEAD: TUBING HANGER: TUBING HEAD TOP: MASTER VALVES: CHRISTMAS TREE TOP CONN.: ' . ~ -( STATE OF ALASKAjf' ' N 0 ALASKA~,~.rL AND GAS CONSERVATION C~ .MISS O ( · WELL COMPLETION OR REcoMPLETION REPORT AND LoGV'- / · 1. Status of Well Classification of Service Well OIL [~' GAS [] sUSPENDED [] " ABANDONED I--I' ·SERVICE [] 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA 82-33 3. Address 8. APl Number aNlr~4n~ac.F aK 9gsn? 5o-733_20073_01 PO BOX 6247 .................. 4. Location of well at surface -~ 9. Unit or Lease Name Cond. 46, Leg 2, 1879'N & 1383'W o¢ SE CDr, Sec. 29t~L~C~~l~ TRADING BAY UNIT 'At Top Producing Interval TDN, R13W, SM. lO. Well Number o~w qu I Surf.~t TBU G-6 RD 372'N & 2405'E of SW cdr, Sec. 28, TDN, ,,-..,,, ..,-,. tS.H' E_ At Total Depth __ . _ 11. Field and Pool 362'N & 2571'E of SW Cor~ Sec. 28, TDN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. RT 99' MSLI ADL 18730 McARTHUR RIVER FIELD 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 4/2/82 4/13/82 5/19/82 143 feet MSL] 2 ,,17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11000' & 9775' liVD YES [] NO [] 300 ! feet MDI ..... 22. Type ElectriC or Other Logs Run OIL-SONIC, FDC-CNL-GR, CBL-VDL-GR, Gyro Survey , 23. CASING, LINER AND C'EMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7" 29 N-80 8509' 11000 8 1/2 6UU sxs ci ~G~ ___ · 24. Perforations open ~o Production (MD+TVD of Top and Bottom and 25. TUBING RECORD [nterva!,'Size and number) SIZE DEPTH SET (MD) PACKER SET (MD) MD TVD HPF 3 1/2" --- 1u280' 9950---9970 ' 8727---'--8747 ' ~3 2 7/8" --- 8/443' 10030-10045' 8806-8821' 13 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10075.10105' 8851-8880' 13 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED_ 10175-10195' 8949-8969' '13" 9950-10195" '135 bbls diesel & U-Eb'o~enc 10368-10398' 91/41-9171' 4 9950-10195 ' 480 bblS acid 8921-8923 150 sxs cl '%" ~, " '~ .... ~' '- ....... '9001'9003 150 sxs cl "G" 27. "' ";pRdDUcTION TEST 10630-11354 3.50 sxs ¢1 "G" Date First P.roduction .I Method of Operation (Flowing, gas lift, etc.) ~?"'5'/~9782 ' ....I?' '~ GaS El'fl"'. ~ .... ' ." ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL G:As-MCF' WATER-BBL CHOKE SIZE IGAS-OIL'RATIO 5/23/82 12- --,Eh,~rl'TESTPER'ODII~ 277- "2izI Flow ~Fabing ~,as~ng ~' ~ cALCULATEDI~ 01L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. r~j~[~ 24.HOD" RATE ! ]/~ "-; ~6 -.",.."' ,582c0R DA.¢~.2 ; '3. ' 32 '' ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chips. NONE ECE I VED . '" :' 'dUN · . , ' :' : ' :" ": ' " ' . '. A!3Ska"Oil'& Gas Cons, Corr~mlssi~.~n ^nch0rage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 4:4 · Ii 29. .,..:.., - " - ' .:,, 30:: GEOI_OGIC M/~ R K ER,q NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/,,G"-Zone 9587, 8370, T/Hemlock 10367 ' 9136 ' None B/Hemlock 10884 ' 9651 ' I · , 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~I~;"'~,~.. ~'~, ~)~ ~ ~. j~ Title DIST DRLI3 SUPT Date 6/15/82 ....... ~-' ' "~ INSTRUCTIONS General' This form is 'designed for submitting a complete and correct well compl.e, tion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in Other spaces on this form and in any attachments. .!!:ltem 16 and 24' If this well is completed for separate production from more than one interval (multiple :.completion), so state in.i:~em 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 (G L) or other elevation (DF, KB, etc.)o Item 23: Attached supplemental records for this well should show the details of any multiple stage cement. lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ' Item 28: If no cores taken, indicate "none". Form 10-407 TUBING DETAIL _ LONG STRING: 1. 3 1/2" Otis "X~I," Nipple- 293' A _ -- 2. 3 1/2" McMurray MN ~. 0 GIM - 2008; ' 3. 3 1/2" McMurray MN 1.0 GLM- 3384' 4. 3 1/2" McMurray MN 1.0 GLM- 4669' B~O_ 5. 3 1/2" McMurray MN 1.0 GIM- 5695' 6. 3 1/2" McMurray MN 1.0 GLM - 6781' 7. 3 1/2" McMurray MN 1.0 GLM 76582_ - i___ 13 3/8" C. 3036' 8. 3 1/2" McMurray MN 1.0 GLM- 8360' o_~ 3 9. 3 1/2" Otis "XA" Sleeve -~8396' C~ ~0. 9 5/8" Baker A-5 pkr - 8430' ioo 4 11. 3 1/2" Blast Joints 9947-10006' D'~ 10037-10135 ' 10166-10225 ' 12. 3 1/2" Otis "XA" Sleeve- 10254' --- 13. Locator - 10292, o_~ 5 14. 7" Baker "F-i" pkr- 10280' DIL E~ 10292 ' DPM 15. 80-40 Seal Assembly 10292-10308' o~ 6 16. Wireline Entry Guide 10309' F ~ ~-~ 7 SHORT STRING: .--~ , A. 2 7/8" Otis "XEL" Nipple - 297' ~G ~ -~ 8 B. 2 7/8" Camco KBMG GIM- 2009' , --: ._~ C. 2 7/8" Camco KBMG GLM- 3445' -- o' 9 E. 2 7/.8" Camco 5963' ~'10 F. 2 7/8" Camco KBMG GLM- 7142' G. 2 7/8" Camco KBMG GLM - 8372' _Il --~ 7" Top 8509' H. 2 7/8" Otis "XA" Sleeve - 8408' I. 2 7/8" Otis "XN" Nipple - 8467' --- --- 9 5/8" Window @ 89~7' ~ "G"-Zone I ! I zoo o- oo4s' 10075-10105 ' ---. 13 ~-- 15~ 14 ! , Gl6 Homlock 10368-10398 -- -- 7" C. 11000' ~. DA~E " , AI'P'D. TBUS G-6 RD , _ ' ,,, Conmenced: 4/2/82 Completed: 5/19/82 UNION OIL COMPANY OF CALIF.~DRNIA , SHEE~S j SHEET FORM 247 (NEW 5/66) March 31, 1982 Mr. Gary Bush Union Oil Company P. O. Box 6247 Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. Boss-16989 Well: G-6 (SEC29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: March 26, 1982 Operator: Everett Sellers Dear Mr.'Bush: Please find enclosed eight (8) "Originals" and five (5) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Each folder presents the survey in Radius of Curvature, Average Angle, Tangential, and Trapezoidal Calculations. Thank you for giving us this opportunity to be Of service. Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures I ECEIVEi) JUN Alaska Oil & Gas Cons. Anchorag~ 0'6 (SEC ::~dRVEY . : . TRAD l NG BAY UN I T MARCH~'-"-;,', 1 '-"-"-';, ,:, ~ ,_lAB.. NLIMBER BOSS-. I ALASKA KELLY BLtSHING ELEV, = ?'~).()C) F'T. MEASURED VERT I CAL VERT I CAE I NCL I NAT I ON D I RECT I ON ... EVER i ]'Y REC:TANGULAR COORD I NATES VERT I C:AL DEPTH DEPTH DEPTH DEG id I N DEGREES DEG/1 O0 NORTH/SOUTH EAST/WEST SEC:T t ON ~ ~ ~ e:~ :::::~::~: :: :: ::::::::::::::::::::::: :::.~i d:: :F::~:: ~':~ j~j~F ~:. [ : :~::~:~ :~:~ ~: :~ ~:~ ~:: : :::~: ::::~: :L::: :: ~.. :: :~.,::,: [::: ::: ::::::::: :::::: ::: : ~[:~: :: ::::::: ::::::::::: ::::: : :::: :: ::::::::::::::::: : : :: :: :: ::::::::: : :::: : S :~.~[ : ~:~: · 20,:h 2'~?'~? '::':' 200.':;"~' 0 4.("~ N 66 :::':'W O. 33 0 ::0 N I =;o W -1 400 ::: 9~7~ ,:~,:~ 300 ':~':~ 0 31 N '=' ~ 30 N 0 '-' '= 0 -"-' .~:._, ,, / ,=, N 2 r: 7 W - 2.67 -- . ~ . + ¢ : ::::::: ::~::' :~:: : ~ ~ ::::: : %.::: : ::::.. .~ : ~ ~ .. 600 ~_,..,,:~:..:::,.~: ::::: ::~ :N :: ::: .-,:./4 W : : :~:~:.~ : :: ::~::,~6~: :~ :~ :::.: ~,,~ :::: ~,] :: :/00: :6::.:,,, ~::~:,::: :. :~,:0~:~: ~<:c, :::: : <:.~: ::::::: :::::: :::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::: 4, ,~,~ W : :i~:~ ~ : :: :~ ~ ~::: ~: :::: ~ b: :~'i%~:: : ::: ':¢~i ~i~~::: ::::: :i ::: :~i:" :: : : ~: ~'~¢: dOC) .... 7.~/Y~: ~2c~ ......... ~.~C), :~t:o:-: .... C) ........ ,~,~, ~.-::~,=*~.,~-.:~'~ ....................... ~:~-~'~ ...................... i--~-~,. N ........ ,J~ ~.,:, W .......... ,J, .~-t - 900 A'~':/_. . .97 800 .97 ("~. 46 o'-' '-'o4 ./-,9_. W 0 .19. I .20. N d, .4.3 W I000 ':~q':~ '~/-, 900 96 0 48 N ':":~ 30 W 0 c)':~ i 1= ..............,_,.. , N 7.80 N -'7.6:3 -,:., ::: : ::~ :~:~?:::::::,~:::: :: :: :::: :: :::::~::~ :::::::::::::::::::::: :::::: : :~ :::: ::::::: :::; :::::::::::: ::~::::=:::: :::::::::::::: :,-,?:~ i z,:U~: :::: ::::: ::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::: :::::: :::():::::::::: ::::::I:~.: ::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::: ::::: :::: ::Y:~:o~,: ~:~" ',': ::::: ::::::: :: ::::::: ~ :: :~T~,~ ::~ :: :: :::~-'~ ::: :::: :: :::: :::: :::: :~' )~: ~: ~:: ::::::: :,~ ~:: :::: :::::::: ::: :: :: ~ : :: :::::"~: ~:: :::::::: :::::::: ::: :: ':::: :::: ,~:: ::: :::: ~: ~:::: ::: :::: '~::::: ::::::::::::::::::: ::::::::::: :::::::::::::::::7::::::::::~ :~,::::::::::::::::::::::::::::::::::::::::: :: :: :::::::: :::::::::::::: '::::-~i:::::::: ::: ::: ::::: :::::::: ~i:::: m~ :: :::: :::: :: : : I =============================================================== :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::: :::::::: :::::::i:::~::::::::::::::~:::: :::::::::: :::::::::::::::::N::::::::::~::~::::~:~:~::::::::::E~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::::~:::::::~:~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::::~:::::i:::t~::::::::N:: ::::: ::::::: ::: :::::::~ o!:::W 1 :_ r,... 0.. 14 ~?. 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UNliON OIL CO, MARCH - ' '-' 1 ,~,,::,c, ,_lOB NUMBER BOSS-- 1698'P 'TRADING BAY UNIT MARUH 29~, .. ,..,~ ALASKA KELLY BLISFilNG ELEV. I] ' "-' ]' " .... VERT Z CAL NEA.=,L RED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY NEUTANULIL~aF~ C:OORDINATES VERI'IC:AL DEPTH DEPTH DEPTH BEG M I N DEGREES DEG/1 O0 NORTFt/SOUTH EAS]" / WE:'ST .:,E _. ] I ON 3200:3010, .:: :~.: :'36 t :86: E---~ -: 690' 60 3300 '-' · :,[ ;.1. 42 2';/';¢2 ........ 42 o'-"o 10 ...,,:. ,_,o-:,._, ._,':'q'.. E 0 4:3 76 09 S 779 '-":,7 E 747 .49' 34C, 0 3 ~ 72.45 307:?. _. 45 o..,""~ :34 S o.:,'-"-' . 0 E 0 .64 ,:,o'-"-'. 0:::. _ S ,;,'::":' c'._, ,_, . 06 E 80:B . v~, 3'5'00 .:'-' ~ '-'=, ~, 7~. ._ 3482, 75 34 ~'-'~, = S ""o~ '~. ~ ';'.. E 0 ~ ~ ~ 1 ~ 9.80 S ~ ~ 2...'::' 84 E 10¢:x]... _. 22 .~ / . .:,o --', ~ ~ ~:- .:~,:, c. 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',~':i :. i~,iil !'::. :: :i' ii::, '?i i:i iii:, ~,:. :.i i i:: i:.ii' ii~ ii :.! :::::. iTii~::i,i;~i i~t:Ji'r.~t~ ~A:;i~i~ --: : ::: : ::: : :~: ~::: :: .::: ~:: :::::::::::::::~t . .: :: :: : :.:: .: :::: ::::: :: :::~:: ::::.: :::::::: ::::::::: ::?::~:? ::::::::::::::::::::::::::::: :::;::: :::::::::::::::::::::::::::::::: ::::::::::: :::::::::::::::::::::::::::::::::::::::::::::: .. ,::::,::::~:: ::::5 ~ :~:2: x: :::~ ~a.:l:~:>Y:m:::i:: x55[ 'llr'~:t::~5~ :: ~: :;~ TRADING BAY LtNI T MARCH .:,c e,2o ,JOB NLIMBER B_ c,.:,'--1 ~ .:¢, 1 ...... = I-i'-'"" 6989 ALASKA KELLY BUSHING ELEV,, =:: 99. ()0 MEA:ql__ IRED VERTZCAL VERTZCAL ZNCLZN~TZON DZRE_.TZON '"r"' SEVERITY REL. TANuL L~R ~ ..... I ' COORDZN~TES VERTZ C:AL I ' ' '""' ' .... I-'" DEPTH E EF TH DEPTH DEG N ~ N DEGREES DEG/1 O0 NORTH/SOLtTH EA:, T/NEST .:,E_. r ~ ON ~',():0() ~.~, *i*:::': ~ ?, ::<~.~ ( : ................. ~ ................. .~ .....:::::::::::::::::::::::: :: ::::::: ~: ~ ::: ...... :::: :*~,,~,: ..... to, s 19 574,61 S 2444,51 E 24.74,49 541 =,0 40 47 ':' ._ 7. E O, 77 _ . 6400 =~':/= '-"~ = '- ,-,c · -,.- = .-,, ~ .: .... ,42/ 6 , ~o._,.:, :q_ 9. 41 S._6.N o .) E 1 , l .~ &o,p_.. . ~'-s ~ =,':' 24 ,2,:,.:/ .... /-,. 9. E .,z...,..:,o'-' =''-' ~ D; '" c ~ ,. .-, ~ - ~= = - .-, ~ ,-. ~= . e ..-, =' ' ,-. .-,='=".- .-',,- - .-',=-,'po .-', - · _,,=, ~ :,. 4:3 34 17 ':' ~":' 30 E O, 79 781, 76 S ~ 7o,:,. :=:.::'-' .... "~ -" E .?::::s, 7000 ~ "~' '-- p;,z~,:~'-, 29 33 46 ,:: .... :,,:,c,(-, 40 =,0ol ZY .... ,.,~ ..., 5I 30 g 0 /6 816.:37 S 2782 81 E . ~ ~..i:.~ .... . ...... ~: ....... ::::::~:::::S ......... ~::.. :;~::.o:.:. .......... E ........................................... :::::::::::::::::::::: ================================== ~,~',8~=,:~::., E ,: ~ , 7 50 0 / =" ' o.:, 73 9 o 1 ~ 1 S 2991 E: 314- i :,::,0o. 34 64o i. 34 ._,= i 6 ,-. oo'-"-:/ · :, 4,_,. E 0 ':": .... :"::' 7600 /- ~,:,a 9:':~ / '-'= ,:. _. ............ =, 4 o .:,, 9 :R '-' '-' .. .:,.~ 1I ._, 47.:R'9 E O.~b: 1027.0'P S :30:31.56 E .::191.76 ~ ](3 /',A/' c/ ~ ~ ~ ' ~ .:~o ,". --,,- " ~,~ - .-, .... , .... ,.- - , ..... .-,.-., //C:, :~ ~ ~,~: ~m,~:C~.::.-,:4 :: ..,~::: ::::1.4 ......... .,:.: ::::~7:.,::.,:,:~: g ......................... ~!::,::~,~ ............... .:,:1-~):6-.~:,:.:~;~:],:~:::::~ ......... ~7:~.), ::~6:.:. .:,~.~, C~:. 7,. ~:~ ~, ::.i:.: .......... ~..,o~,:.,:~::I::::: :,~ ~6; ======================== ~.:~::~: ::.:.:., ~:.:~.~.,:~ ~ : , , J:.~: ~z: ~., · ~ :~.~ :: : :: : ........ :: ::::: ~ ..... ~:~ :::::: :::: : :::::::: ..::~:: ::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::: ..................... ::~::::. :::::,~.+~ ................................. ~:::r~..::,,:::::~t ......... ~ ............ ,.~ ............ ...... ::.~:~:::~ ::~ ..... ~t::~ ....... ~ ~,~:::, ,~: :::: · :::, : :: - o0oo ::::ts,:::. ~6 ~:~:,:,:,. ::-:::: ~-=;~:7:~:::~-=,:: :.:::: :::: :::: -:3::~:377:4:;-: 8100 7014, :31 691 ._, = , :3 i 29 20 S : c) 0 E: 0, ' =; .:,.:,-:, o .-., ~., .-,--, (:,._ 1 197 60 S 1 E .:,4,:,..:,, 92 g:?O0 7100 '-'= 7C)01 '== ' ..... o._, :q 0 47 S = · _,0, 10 E 1 45 1229 7'7 S :q21-,() 61 E .:,4ol :-~5 8:300 7 :q:~: 2 70,:,'~, o o- .:,,~1 o = c, .-, .-,- .-,-- ~..-, ,-. .-,.~,-,,-, ..-, -.- .-,~=.-,~-, -.~ .. ::: 1-::-:,:! ~:: :: ,:,_,..::.,1.~ . ,:-::. :~:Z: .-:~: ::::::::::::::::::::::: ...... .::i:~:~o:g~:,:~,::.,= :-.o:- - .;,-,:=~-~.o~:.:,4: ~:,- : .::.,,.,,~,o~ 6 : ~ :~ ::::: :::::: ::: :::::::Y~:~7:_~:::~ ::,::,:: :: :: :::::: ::::::::::::::::::::::::::::::::::: :::::::: :: ::: :::::::::: :: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: o::::::: :: ::::: ::: ::: oo: ::: ~::~::)% ~:::: ::::: ::::':: ::::::::::::::::::::::::::::::::::::::::::::::::::::: :: :::::: ::: :::: :~:':::'::::"~::'~ :::::::::::::::::::::::::::::::::::::::::::::::::::: ~'*~ z.::: :::.:.: :. :: ,~: ::::: ~, '~;~ :~: :~: ~:,~:.::: '~,: : :~,~'~ ~, :::: .... 7 () (] ~/R._ ~." I , ,_,':' 47. ~.~ :l ~'-, . '-'o 4 2~...':'19. .:,'-' ._=; ~'/ ,6 0 E 0 , ~/:"" 1 ._,':'/-_, ._:. 6 2 S o'-' 4 :._ ~: ¢' , 2 4 E :'::: .... 7 i :[ . 35 8800 7629. 18 75:30 I8 28 ':'-' ': .... ~ ,:, ~ A, 69 E 0 ::,6 :l 392 04 '.3 -:, a,:;-':: i 6 F:' ":' 7 ~:;'::, :34 0,~,("1 '") ~ '~ ~- :~'~" 7 & "= 0" '~,,D -':, :-. ~ ~ :-," '" ." w · ,-, -r" ,"'. .-, ~:z .-, .-, ." :'", " .'" r', .". · ~:' .' t '~'-,-'~ ~,EI, :::.~:': --,': ...... ..... ~ .................................... ~ ............ ~ ,~..~ .... ~ ~, , ~ .,~* , )~ TRADZNG BAY UNZT MARCH 29, 1'~82 dOB NLIMB~R BOSS-16'F'8'~ ALASK~ KELLY BUSHING ELEV. = ~79.()0 F'T'~ VER,IC;AL MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY REC:TANGULAR COORDINATES VERTIC:AL DEPTH DEPTH DEPTH DEG MiN DEGREES BEG/1 O0 NORTH/SOLITH EAST/WEST SECTI ON ?300 8066.09 7':'67.09 :30 49 S 53.89 E 1.05 1530.29 S :36'~':3. O0 E :39t:~7. :3:3 '~400 8151.50 8052.50 31 51 S 54.10 E 1.03 1560.86 S 3735.07 E 4048.02 ...... ::: ::: :: ::::::: HF~ R::~: ~:i:i~:~ ~:~::::::::::::: :: ::::::::: ::::_:.:.: ._:i :::::::::::::::::::::::::P:kA E~M:N.: ........... ~::~,..,~::~ :: ~.:.. :< ::.ET:~ ~:. :::~,~:~~':~~:::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::: ::: ::::::::::::::::::::::::::: :::: ::::::::::: ;:::F::::::: :::::::::::::::::::::::::::::::: ::: ;;:~ ::::::::::: ::~:==========================::::::::: :~:: ::~::::: :::::::~: ~: :::::::::::::::::::::: :::: ::::::::::::~: :: ::::: :: ::: ~:: ............. ::: ::2 :::::: :~::;:~0~::::: :?: ::::: ::::: ....... ::: ::: :: :: :::::: ::: :::: :: ::: :: ::::: ::: ::: :: THE C:ALCULATION PROE:EDLIRES ARE BA::,ED'-' ON THE USE OF THREE DIMENSIONAL RRDIL._-."" I'" OF F:IIRVATURE_.. METHOD ]'RF~iDING BAY LINIT MARCH 2'F~, 19:32 .JOB NUM/~ER E~OSS-.16S~8'P ALA'.SKA KELLY BLI'.SHiNG ELEV. = 'P'P.00 FT. TRUE SUB-SE~ TOTAL MEASURED VERTiCaL VERTiCaL RECTaNGULaR COORDiNaTES MD-TVD VERT~C:~L 2000 1987.31 1888.31 19.09 S 107.81 E 12.69 12.65 3000 2850.37 2751.37 56.29 S 602. :39 E 14'P. 63 136. 400u o664 ,.:~ ..... o..,16.~,:-,~:.:,, : -~:-t27~4 ~l~!~7:~,~=..~ E:~::~::~-I !~--,:,::, ...... ::.::: : l :3000 6926.88 6827.88 1166.54 S :3184. 'F~:3 E 1073.12 154.4 i '~000 7804.87 7705.87 1445.36 S 3572.45 E 111~5. i2 122.00 '-' .'.~c,.,~. ,JO~ NUI'd~ER Bf]SS-;I. .... ,_,.. TRAD I NG BAY LIN I T MARUH...'--"--...~ ~ 1 '- ''~''-' /- ':;"::'":'~ ALA.'_--;KA KELLY BLISt--tINr.:i ELEV. = '::;".':;'. ()0 FT,, TRUE .=, _IB-._-,EA TOTAL MEA:--;URED VERTICAL VERTIF:AL RECTANGULAR C:OORDI NATES M£;..-TV[~ VERTICAL DEE, TH DEF'.TH DER.TH ........ NORTH/'.-:;I]I.ITI4 ..........EA~.T/:WEST DIEF-ERE4~PF-.;E .... :-CORREOT--I::ON .... - - 1 ,.7¢,:? i :-?'.~. O0 i O0. O0 0. i 5 N 0.77 N 0. O0 0. O0 ~: .-,'.-., :dW'~/,, O0 200 O0 0, ='¢ , .... ,.:' N 1 57 W O. Ol 0 O0 3':.,9 . 3'P'P. (':,0 ..... 300, O0 · , ,;,~..~:,=,..N : ........... ~.,,-.,~/=,,.W~ ::. -.,0,-0 t.-.: 7'.':'/'? 7'p::? O0 700, O0 i '-"'-' = ":"-':' ,,~,_-, N W 0 ]'"" - .-,..~.~ . :=:9':/ ,=:,-s..-s, O0 800, O0 1 ":" -.. .- ....... .~I N 6,41 W 0.03 0.0I :: ,"'~,~'"~: ::: :::::. ::: :::~~i:i~ i~:: ::::~ ::: ::::: ::::::::: :::::::::::::::::::::: ::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::::::: ::::::: ::::: ::::: :: ::::: :~:::::::: :~::~,: ::: : : : i ::~ ...... 99 1 :':,' 99 .00 i :2_ O. <'~.. 00 0.63 N :3 .9. 9. W 0 .20 0 . 1 .~:'" 149':.' ..... 14'P'P, O0 1400 ,, O0 1 ~4. :=," 4. . C,6 E 0 ,.=i._ 7 0 .5:7 i600.: 15:~'.-?., 00:: ::: ::i500:, 00,: ::: :::::::::::::::::::::: , <:: ~::~ :::::: ::: ~:.: ::::::: :::: :: :::::::::::::::::::::::::: ~.::: .:::~ ::~::~::.~ ::::::::::::::::::::::::: ::::::: i: ,:::~ :~: : ::: ::::: : : ]., r.~,,~(t ~::~ ) : ::::: ::::::::~.~::::: ........ .... ,~'~]: ....... ~ (: ~:( l : :: ::::: :: : :: ::::: ::: :. ! :~::,: O: .:( ill l:~ ...... ~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:::~ ~:.:::~: ~¢ .......... ~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::~::j~ ................... ~.' _/~i ~ .............................. . ............................. ~-. :::..~ TRADtNG B~Y UNZT M~RCH 29, 1982 dOB NLIMBER BOSS-16989 ALASKA KELLY BUSHING ELEV. = 99. O0 F"F. TRL E ,at IB-F;E~ TAT~L MEASLIRED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL DEPTH: DEPTH : DEF'~H 2118 2099.00 2000.00 21.37 S 147.5'7 E 2227 ':'199 O0 2100 O0 ~ . ~ ..... 74 S 19o 1q' E '-'~ 34 ""' 74 ..: ..~ ..... . ..... 28 ~ 4 "' '~'- z~:,. y. O0 2E,(](]... O0 46.09.. S 4'9~, _. 20 E :[1~._,. ..':":'.., 21 .20 · -.oo/_ ~'::' 6,6, S E 137 ~l(") 22 26 .~ .... ~ .... 2799 O0 2700 O0 ~z:~ '-":' ,:, · .,,':' ,': -, ~ / ~, ._,':' ....,':' '~'.. q'... 00 ._~.~':: ':: A A. ~ 00 103 :3799 '~''-":~ 'C '~' ......... ' "':~ '-' C ' = - '-'-" z'-' '~' :: :: :: : : · : TRAD I NG BAY UN I T ' MARCH 2'.-.9, 1 '.~82 dOB NUMBER BOSS--_1./_-,'.:.78'~' ALASKA KELLY BUSHING ELEV. = 'f'RUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL t-' 'T : , ~-, .',--~ ,-. ~ -r-o . ..... : -... _:~ :.: ~_. ._ i :: :,~ ~' ::~ :::: ~" ~-, ~i ,~':: : : '..~,,~ :: .: .::: ~t'~ ::: :: ::::::: :: .::::~:.~i~ ]:~'~"~ ::~ :: ~:~:: : 4402 3999.00 3900.00 ~53.3~ S ~3'~9.37 E 403,47 20. Z$ 4523 4099.00 4000.00 ~74.8~ S 1466.30 E 424.35 20.88 : : ¢~ ~ : :~ ..,~;~;~¢: :::,:,¢ :. ~,,~: :::: :~::,.::::. :: : :: ::Li~::~ ::: :: :: :~; :: ::;~ :::~;~;~¢:::::::::::::::::::::::::::::::::: ......... :: :::::::::::;:;::::: , , : ::: ::: . : ::::: :::; ::::: ::: :;:::::: :~::: ::::::::::::::::::::::::::::::::::::., ,.. :::::: :: :: : : : 5 ~ 37 451~'~. O0 4500. O0 260.83 S ~ 81 ~. 43 E 538.37 25.55 5261 46'~'~.00 4600.00 284.18 S 1881.63 E 562.77 24.:B';~ : . ~:~::~ ::: :::::::::::::::::::::::::::: ::::~ :~: ::::: :::::: ~: ::~ ::~.:. ::: ~: ::.~: .~.~ :~::~.::,~,::::: ============================= ~.~:~:;~ :~ ::::::::::::::::::::::::: : :::: ::~ ~ ~::~ :~ :: :: ::. ;:, ,, : ~:~: ..... ~-~,i.~::~:_t:lE~ :,.. .:~:~Elt).i~ ~ ~:li~::: ............. ~¢~::~ .... ~:: ::e; ...... ::::::: .......... ~:,~:::.~:~::::~h~C~ ..................... ~.~-:;~: ~2 ~:~:~-~:'I/~ ' ' 5877 5 ~ 3:'9, O0 5 ~ 00, O0 432, 35 S 2207, 87 E 678,33 25. ~ 4 6007 52'~9, O0 5200, O0 473, 7]. S 2280, 02 E 708, 4~ 30.09 : : :: :::: : ::: :::: ::: :. :.:: :.:; :.: :.:::::::::: : : ~ ::::; ~: t~::: ~ ::: ::::: .::: ~: ::::::: :::::::: :; ::::: ::: ::::::::::: :~: ~: ~::: :~: :: ~.:::::: :.:: :.: ;.: ::: :~.:.:,: ~ .: ~,::.:: ~:.~.:::: :....:: :::: :.::: .:.:::;::::;:::;:: :::: :::::::;: ::: ;::::: ::::::.: :::~:::: :::::::~ :::::::::::::::::: :: ;:::::::: :: ::::::: :; :::: ::: :::-~ ~ :~:; ~ ~ :: : :: : : : )::~ : ::: :::: ~::~:;~:: :: ~:::~ : :::~ ~.:~ :~ :~ ::~:~::: ~ :: :::::: : ::.- : :: '-~:: ::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::¢i:::::::::::::::::::::: :::::: :: j:: :-~ 4~:j~: ~: ~.::: ,::: : TRADING BAY UNt]' MARCH 2'~,, 1782 ,JOB NLIMBER B08S-16'.:..:'8'.:.;' ALASKA KELLY BUSHING ELEV. '= ':':?'i~.'.O0 TRUE SUB-SEA TOTAL NEA, SURED VERTICAL VERTICAL RECTANGULAR COORDINATES ND-TVD VERTICAL ~ ~-~'~.~ :,~:'.:::::::'~": '~:: : :: 5 J5 :~"~:5:::2 iii: : ~ : 6779 5899.00 5800.00 740.16 S 2684.07 E 880.11 22.96 6'~'00 53~'9";'. 00 5'F~00.00 782.00 S 2739', 14 E 'F/O i. 70 21.59' 74'F~8 64'~'~. O0 6400. O0 '~t:~O. '~5 S 2991.20 E '5'?'~'. 41 i 8.66 7516 65t~t;'. O0 6500.00 1033.03 S 3038.13 E 1017.62 18.21 ~ ~: ::, : :: 5.:::,. :6 ~ DO:~:::O:O:::: ::: :::::: :: :: ::: i: :t:::D6:~:::o D:: ::::;~::::: ::: ::: ::::: ::: :: :::::;=!:~::~::-:~:~ ::;~:::6::: E :::: ::: :i::~;~:,::;~ ~: :~:::~:: ::::::::: :::::: ::: ::::::::: :: :: :::: ~ :~, :. :~:7::: ::: :: 81 t97 7Pc/o' O0 ~< ......... 5.4 .... :,~...,; . 77 E 10t98.84 I . 1 8312 71 '59.00 7100. O0 1264.30 S 3302.77 E i i 13,,28 14.44 84'?~ 729':?. Cx] 7200, ex] 12'~,7 ':..-,~-- -::::~? :::~ :~:4...~. .... ....... ~. ~X;'.A ~:-:;:~-:-: : - : . ! c: ~.-~].~t - .... ~'-- : , , .* ~ ~ : : ~ . :-: ~ ~:': ',,::: ~ ~:I:.~: :: ::::: ::,--:~:-. ~': ~:-~:':::~:: :::: :::::: ::.:: ::::::::::::::::::::::::: ::::: : _,~ ~ .¢ ~ '~:'~: : ~'''r~ ~' ........ ~:~ ::::: :: :::::::~::~:~!:::::~ ,,. .... :::..,:~'-.: :::::::::::::::::::::::::::::::::::::::::::::::: :~D~::::::: :2 :: : : : : ~ ::::: ::s~5:~::::::'~ :: ::::::::: :: ::::~ "'~:'"::::::::::::::::::::::::: :::::::::::::::::::::: :? :7:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ? :::::::::::::::::::::::::::::::: '-"' :: -: ~ : ??:: ::::::::: ::::::::: :: :::::: ::::::::::::::? ::: 4:::;::: ::::::~::::: ::: SP, ERRY=,::SUN, .WEL L-~ S URME ¥'.ZNG-: COIdF¢¢4NY. ..... ~ TRADING E4r~Y LINIT td~RC:H 29, 1982 ,JOB NUHBER BOE;S-i ¢~LASt<:~ KELLY BUSHING ELEV. = 9'P. OC} F'T. TRUE SUB-E;EA TO T~4L IdEASLIRED VERT I C:AL VERT I C:r~L RECT¢~NGULAR COORD I NATES MD-TVD VERT I C:AL I ~' I ' I- ' """- ' '-" "-" .... ,- E~EF'TH ~ EF TH DE~ TH . NJR~H/.=,uUT H .... E~4.~.~/.NE,:,] .... DI.FFERENUE C:rtRREr':T I 8879 7a;:m~, oo: ::: 99 ::: 7799.00 77 (} C} 00 144:3 Pi 9 S '-' ~ ' o ,:,-:, E 1194. '-' · .:, ~ 'P 107 - '"'''- '~' 9222 79'P9~ O0 7~00, OD 1507.16:~S ..... 3~,~,0., 99~.. E .... _ ~22;3, 15 ,:~ ~d. c 0 :~ ,~,,~i '1:,~ c: : ~,~ ~: ~ ~ :: ~ : ~ iY,: ,~;Y~: ::: ;y~: ~ : :::: :~ti;~"~:~ :~ :: ; ~ c:: ~: ;~i~!~i.:~: ~::;~;;:::: .: :4:,,.~ :: ,_~1 :~ z (JO:: : ,:,~:00, ~0 : :.: :::t .~7:,:, ;:~=~' ":: ::,~i~:~ ::~ ~::: :: : ::::,::: : 7 ~:?i:::;~:: ~::: : :~;~;:': ~;~;;:~;~;~:.:: ~:::~:i!:;: 7::~s:::2 7 : 96 C) 0 8:319 '~ = ':,",':' C, 75 1 / '-' ':":' '-": /..-, ,-,=~... :.~.4 7.5 S '[2:RC) ...... ~.~ ZW E 4.04 THE : CALCLILATION: F'ROCEDUREE; USE A :: LINEAR :INZERF?LATION BEZI~EEN .......... TI".E :NEARE..,T ~,::)FL!:UT : --2000.00 -50~.00 TRUE NORTH ~ ~ .... ~ -~ --1000.0 · Union Oil Company. O~ ~SS ~roscopic S~~ Well: G-6 (SEC29 ~N ~ading ~y unit -- 1500200 ' Kenai, Alaska _ S~ey ~te: ~rch 26, 1982 ~rator: ~erett Sellers Meth~ of ~lc~ation: Radius of ~t~e ' Scale: 1" = 500' HOR I ZONTRL PROJECT I ON 9600 0.00 2000.00 ~000.00 6000.00 8000.00 Union Oil Company Our BOss Gyroscopic Survey Job No. Boss-16989 Well: G-6 (SEC29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: March 26, 1982 Operator: Everett Sellers Method of Calculation: Radius of Curvature Scale: 1" = 2000' 4153.27' @ S66° 58'E 9600 i 0000.00~ ~o~o. oo ,~obo. oo sol~o, oo VERT I CRL PROJECT I ON UNION OIL CO. OF CALIF. G-6 TOTAL D I RECT I ON ANGLE 1] EF TH [lEG DEG M i N 0 N 0.0 E 0 0 100 N 86.7 W 0 17 200 N 66,.0 W 0 20 300 N 6,6.4 W 0 4-0 400 N 85.:} W 0 31 500 S 78.0 W 0 19 600 S 83.6 W 0 I2 700 N 50.9 W 0 35 800 S 88.4 W 0 36 900 S 84.7 W 0 47 !000 N 89.3 W 0 48 1100 S 88.7 W 0 40 1200 S 68.0 W 0 14 1300 N 84.3 E I 46 1400 S 77.6 E 3 34 1500 S 73.3 E 6 0 1600 8 72.9 E 9 4 1700 S 74.5 E 11 39 1800 S 82.4 E 13 11 1900 S 85.6, E 15 20 2000 S 86.4 E 17 45 2100 S 86.9 E 20 55 2200 S 86.8 E 23 55 2300 S 86.7 E 27 3 2400 S 86.0 E 30 9 2500 S 86.1E 32 30 2600 S 85.6 E 33 14 2700 S 85.2 E 34 7 2800 S 85.0 E 34 39 2900 S 84.5 E 35 19 3000 S 84.4 E 36 11 3100 S 83.5 E 36 49 3200 S 83.5 E 36 36 3300 S 83.4 E 36 10 3400 S 83.0 E 35 35 3500 S 82.9 E 35 34 3600 S 82.8 E 35 13 · -, ...... o.-:, 7 E 34 ...... · .:, ! (.)(.) '.:: .... ,.~., 3800 S 82.2 E 34 32 3900 S 82.2 E 34 25 NL SPERRY-SLIN, INC. VERT I CAL DEF"FH O. O0 100.00 200.00 299.99 :399.99 499.99 599.98 699.98 799.98 899.97 999.96 1099.95 I199.95 1299.93 1399.82 1499.48 1598.61 1696,.99 1794~64 1891.56 1987.43 2081.79 ~174.24 2264.51 2352.31 2437.73 2521.73 2604.95 2687.47 2769.40 2850.55 2930.93 3011.10 3091.61 3172.64 3253.98 3335.5(} 3417.33 3499~50 3581.94 LATITUDE FEET 0.00 N 0.01 N 0.14 N 0.50 N 0.75 N 0.71 N 0.63 N 0.83 N 1.16 N 1.08 N 1.03 N 1.02 N 0.86 N 0.83 S 1.10 S 3.20 $ 7.01 $ 12.05 S 16.36 S 18.93 S 34.02 S 37.94 S 42.39 S 47.21 S 52.46 S 58. i1S 6,4.38 S 71.15 S '77.~2 S 84..85 S 91.99 S 99.:20 S 106=46 S 113.94 S 12!.63 S DEF'ARTURE FEET 0.00 E 0~26 W 0.80 W 1.60 W 2.61 W 3.34 W 3.79 W 4.44 W 5.42 W /-,. 62 W 8.00 W 9.28 W 10.05 W 9.6,3 W 4.99 W 3.09 E 15.63 E 32.88 E 57:. 95 E 78.45 E PAGE .i. B 0 S S-" i t,5989 MARCH 27, i982 VERT t CAL LIL.,L~ S E C ]" I 0 N L. E G 0. O0 0. O0 -0.24 0.29 -0.78 0 :, 12 -i. 66 O. 33 --2.69 0,,, 25 -*3.34 0.23 -3.73 0. t 2 --4.40 0.46, -5.43 O. 41 -6.51 0= .19 -7.75 0. (39 '"' 9:--: -c: ..... 1 :B -9.5:9 0.46 - 8 ,,._P; ._,':' i .98 -.4~ 16 1,,97 4.09 2.45 17.12 3.06 34.97 2.61 56.05 2.5!:9 79.60 2.28 894.87 E 859.42 0~06 952.32 E 915. 10 0,:35 10, C, 9 "" z ,-'. ~',',"~, '::,/- . ,:, 1. E ::, / ~.. 4.10 1065.84 E 1025, 33 0,52 I .1. 21,92 E .1.. ()79,, 5;'4 0 ,, 11 601.46 E 576.18 0.87 660.62 E 633.07 0=83 720.(}1E 6,90.37 0.22 778. P5 E 747~24 0.43 837.14 E 803.50 0.63 320.55 E 308.26 2.35 374.6,7 E 359.60 0.78 429.94 E 412.20 0.92 486.21E 465.86 0.54 · .. 4. o :B 1 E .4..., 73 106.85 E 106.51 2.43 1 :::9. "" ' ~ _. ::, 0 E 1._,':' v.. 6 / 5:.... 16 I77.96 E 173.51 3.00 220.91E 213.99 3.14 268.68 E 259.14 3. I2 UhiION OIL C:O, NL SPERRY-F:;UN .-, iNC, B 0 S 'S - MARCH 27.. TOTAL D I RE_.T I ON ANGLE VERT I CAL LAT I TUBE DEPTH DEG BEG MI N DEPTH . FEET ~.:l' lt'- EEF RT.. Rb. FEET V E R T I C A L D 0 O SECT I ON LE:G 4000 $ 81.8 E 34 9 3664.56 4100 S 81.1E 33 56 3747.43 4200 S 80.9 E 33 37 3830.56 4300 S 80.4 E 33 29 3913.90 4400 S 80.0 E 33 50 3797.14 129.47 S 137.79 8 146.48 S 155.46 S 164.89 S I177.70 E I134.34 0.35 1233.06 E 1188.53 0.4.5 i287.96 E 1242.45 0.34 134.2.48 E i296,,&4 0.31 1:397.10 E 1350,,09 0.42 4500 8 80.4 E 34 24 4079.92 4600 S 80.0 E 34 12 416:2.53 4700 S 79.7 E 34 3 4245.3~ 4800 S 75.1E 34 4~ 4327.85 4900 S 74.0 E 36 t3 4409.31 174.44 S I84.03 S 193.92 S 206.23 $ 221.69 S 1452.38 E 1404.69 0.60 1507.'71 E 1459.54 0.30 1563.13 E i514.22 £3.23 1618.22 E 11_ 569.74 2.67 1674.13 E .t627.22 1~65 5000 S 73.2 E 36 46 4489.71 5100 S 73.0 E 37 24 4569.49 5200 S 71.6 E 36 i9 4649.50 5300 S 70.1E 37 1 4729.70 54,00 S 68.0 E 36 28 4809.84 5500 S 66.3 E 35 26 4890.79 5600 8 65.0 E 33 23 4973.28 5700 S 63.9 E 34 26 5056.27 5800 S 62.0 E 36 22 5137.77 5900 S 60.6 E 39 2 5216.8~ 238.47 S 256.00 S 274.24 S 293.83 S 315.22 S 338.01 S 361.32 S 385. :::8 S 411.73 $ 4.41.10 S 1731.:[7 E 1788.86 E I846.00 E ...0z..42 E 1958.28 E 2012.38 E 2063.87 E 2114.21E 2165.81E 2219.45 E 1686.28 (3.73 1746.23 0~65 1805.95 1865.54 !.14 1925.3~ i.38 1984,.02 1.43 2040.52 2.18 2096~ 27 1 .~'-"-' 2154.06 2~22 2214.92 2~79 6000 S 59.6 E 40 47 5293.59 6100 S 59.1E 41 38 5368.82 6200 S 58.0 E 41 21 5443.72 6300 S 57.2 E 40 47 551~.11 6400 $ 56.8 E 39 42 5595.43 473.08 S 506.67 S 54.t. 24 S 576.44 S 6_1. I.63 $ 2275.07 E 2278,, 62 ! ,, 87 · .' ..:,.:, 1,75 E ,~...:, 4.:.,, '.:.;':2: 0 '.:.,' J, 2388,27 E 240'?, 48 0 ~ 78 ": .... 75 = 4. 4...:,.E 24. 74. :":i: () 0 77 2497.93 E 2537,, 94 1.i2 6500 S 55.2 E 37 16 5673.72 6600 S 55.0 E 36 11 5753.86 670¢3 S 53~9 E 35 46 5834.79 6800 S 53.1 E 34 56 5916.34 6900 S 52.3 E 34 17 5998.64 646.4.2 S 680 ~ ''"' ':' 7~4,7~ $ 749,2~ S 783.63 S 2549.51E 2599,,03 2.64 2598.56 E 2657.55 ~.08 2646.36 E 2714,.9& 0.77 2692.87 E 2771.19 0.95 2738.06 E 2826.25 0.79 7000 S 51.3 E 33 47 6081.50 7100 S 51.0 E 33 37 6164.70 7200 :2; 49, 9. E o"~.:~ ''~ ._,':' 6:248 , ,~':' ~=; 7300 S 50.0 E 32 50 635:2. I8 7400 S 49.4 E 32 46 6416.23 818.24 S 853.04 $ 888.03 S 923.02 S 958.06 S 2782.04 E 2825.25 E 286'7.6! E 2909.24 E 2950.55 E 2880.27 O. 76 .,:::'?..::,:": ~:, ::, 0 ~. 24 2986. :2:4 0 ~ 82 o0-:,o :34 0 23 3090.08 0.3:3 750C, b ':' . ........... '" 4.,_,.4 E 32 i/-', /-_,..=,oc3 7600 S 4.7..,9 E 32 I1 6585.14 770(.":, S 47,, 4 E 32 14 .e.,669.74. 7800 S 46.4 E 32 i6 6754.3:t. 7900 S 48. i E 2'F..' 57 ,:':,8:3'F'. 'F'3 993.40 S :[028.98 S 1064.89 S 1101.36 S 1136.43 S ":":'."::"I ¢:,/.:, E 303(). 79 E :z:07C,. J. 9 E 310'i.:;'. i,':., E 3147,, :I. 0 E 314.1...t9 0,, 73 319:[. 68 0,, 28 :324- :I..., 99C,. ::;:': 7 3292,, .1. 3 C,. 53 F):'::40.78 2,, 48 UNION r].'[.l_ CO. OF CALIF'. G-6 TOTAL D I RECT I ON ANGLE DEF'TH DEG DEG MIN NL SPERR¥-.?::;LIN: INR. VERT i _4'4L LAT I TLIDE DEPTH FEET ::::':':"~] (':~ S._,'U -'= ' .4 E .~'-",_, '=' 43 /-,_ '?..,..'.';' 7 .10 1 t ,..":,:=:_ . 41 S 8100 S 50.0 E 29 20 7014.54 1199.4,7 S 82(:~0 S 50,,1 E 30 47 7101.08 1231.64 S 8300 S 5! .2 E 27 38 7.1.88.36 1262.59 S 8400 S 51.0 E 27 57 7276.82 12~1.87 S 8500 S 58.5 E 25 19 7366.21 1317.74 S 8600 S 59.0 E 29 32 7454.97 1341.63 S 8700 S 57.6 E 29 !9 7542.07 1367.44 S 8800 S 56.7 E 28 58 7629,,40 1393.86 S 8900 S 55.8 E 28 25 7717. I3 1420.53 S 9000 S 56.0 E 28 22 7805.10 1447.19 S 9100 S 55.0 E 28 54 7892.86 1474.33 S ?200 S 54.6 E 29 50 7980.01 1502.60 S 9300 S 53.9 E 30 50 8066.32 I532. I1S 9400 S 54. I E 31 51 8151.72 1562.68 S F'AGE..:, BOSS-1 MARC:H 27, I982 DEPARTURE VERT I CAL DOG FEET SECT I ON L_EG 3184.2i E 3387.45 1.67 322t.49 E 3433,,92 0.65 3259.90 E 3481.85 I,,45 3297.64 E 3528.70 3.20 3333.93 E 3573.56 0.32 3370.54 E 3/:, 17.37 4.27 3409.91 E 3662.'95 4.23 345.1.. 70 E 3711.52 0.72 3492 62 E .... . ..:: / ...':,'.-.~ ,, 51 0. h, ,/-, 35:32, 54 E 380/:, ~ 69 0, 7-!. 3571.91E 385:3.35 0. i0 3611.40 E 3900.32 0.7i 3651.48 E 3948.27 0.96 3692.47 E 395~7.54 !.05 3734.54 E 4048.23 1.03 THE DOGLEG SEVERITY iS IN DEGREES PER ONE HLIIxlDRED FEE'F, THE VERTICAL SEC'TiON WAS C:OMPLITED ALONG S 66 P; ,.7 E BASED LIPON AVERAGE ANGLE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 4153.50 FEE']', IN THE DIRECTION OF S 66 57 E BOTTOM HOLE DISPLACEMENT IS RELATIVE TO WELLHEAD. VERTICAL SECTION tS RELATIVE TO WELLHEAD. -~0~.00 TRUE NORTH '~ ~ ~oi~. oo ~oob. oo~ ~ob. oo --5oo.'oo, · ' ~ Union Oil Cor~any ~ ,.S%'~-O'-~. ~ . Wel%~ ~6 _(SEC29 TgN R13W) ' ....... ~_~ ~ . Kenai, ~a~ka - '~.~ ~ ~t~d of ~lc~ation: Average ~gle Scale: 1" = 500' -2000.00 9600 HOBIZONTRL PROJECTION ' 0.00 2000.00 Union Oil Compan~ Our Boss Gyroscopic Survey Job No. Boss-16989 Well: G-6 (SEC29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: March 26, 1982 Operator: Everett Sellers Method of Calculation: Average Angle Scale: 1" = 2000' · 4000.00 8000.00 8000.00 10000.00~ 4153.~50_'___~ S66° 57'E ~o~o. oo ~o~o. oo ~6~o. oo VER T I CRL PROJE C T I ON NL SPERRY-SUN, I NE:. PAGE i UNION OIL CO. OF CALIF. G-6 TOTAL D I RECT I ON ANGLE VERT I CAL DEPTH BEG DEG MIN DEPTH 0 N 0.0 E 0 0 100 N 86.7 W 0 17 200 N 66.0 W 0 20 300 N 66.4 W 0 40 400 N 85.3 W 0 31 500 S 78.0 W 0 19 600 S 83.6 W 0 12 700 N 50.9 W 0 35 800 S 88.4 W 0 36 900 S 84.7 W 0 47 1000 N 89.3 W 0 48 1100 S 88.7 W 0 40 1200 S 68.0 W 0 14 1300 N 84.3 E 1 46 1400 S 77.6 E 3 34 1500 S 73.3 E 6 0 1600 S 72.9 E 9 4 1700 S 74.5 E 11 39 1800 S 82.4 E 13 11 1900 S 85.6 E 15 20 2000 S 86.4 E 17 45 2100 S 86.9 E 20 55 2200 S 86.8 E 23 55 2300 S 86.7 E 27 3 2400 S 86.0 E 30 9 2500 S 86.1E 32 30 2600 S 85.6 E 33 14 2700 S 85.2 E 34 7 2800 S 85.0 E 34 39 2900 S 84.5 E 35 19 3000 S 84.4 E 36 11 3100 S 83.5 E 36 49 3200 S 83.5 E 36 36 3300 S 83.4 E 36, 10 3400 S 83.0 E 35 35 3500 $ 82.9 E 35 34 3600 S,..,°.~'-':'. ,_,o E ..:,'-'.::, = 1..,":' .... :,.Z./ E 34 ...=l':',.., 3800 S 82.2 E 34 32 3900 S 82.2 E 34 25 0.00 100.00 200.00 299.99 499.98 599.98 699.98 799.97 899.96 999.95 1099.95 1199.95 1299.90 1399.70 1499.16 1597.91 1695.85 1793.21 1889.65 1984.89 2078.31 2169.72 2258.79 2345.26 2429.60 2513.24 2596.03 2678.29 2759.89 2840.59 2920.65 3000.93 3081.65 3162.98 3244.33 3326.04 3407.99 3490.38 '-'=~'-' 87 LATITUDE FEET 0.00 N 0.03 N 0.27 N 0.74 N 0.81 N 0.70 N 0.66 N 1.30 N 1.27 N 1.14 N 1.16 N 1.13 N 0.98 N 1.29 N 0.06 S 3.06, S 7.69 S 13.09 S 16. Ii S 18.14 S 20.05 S 21.98 S 24.24 S 26.86 S 30.37 S 34.02 S 38.22 S 4.2.92 S 47.87 S 53.41S 59.18 S 65.96 S 72.71 S 79.4-9 S 86.58 S 93.77 S 101. O0 S 108.28 S 115.97 S 1'-"-' 64 E; DEPARTURE FEET 0.00 E 0.52 W 1.06 W 2.13 W. 3.03 W 3.58 W 3.93 W 4.71 W 5.76 W 7.11 W 8.51 W 9.68 W 10.05 W 7.00 W 0.91 W 9.11 E 24.16 E 43./_-,2 E 66.24 E 92.59 E 123.02 E 158.66 E 199.13 E 244.53 E 294.63 E BOSS-16989 MARCH 27, i982 VERTICAL DOG SECTION LEG O. O0 O. O0 -0.48 0,, 2:9 -.1.07 O. 12 -2.24 0.33 -3. 10 O. 25 -3.56 O. 23 -3.86 0. 12 -4.83 0., 46 =' 78 C, 4.1 -6,. 98 O. 1 ':'::' -8.27 0.09 -9.3:4 0.. 13 -9.62 O. 46 -6.93 1.98 -0.81 I. 97 9.58 2.45 25.24 3.06 45.25 2.61 67.24 2.29 92.28 2.28 121.01 2.43 154.54 3.16 192.65 3.00 235.43 3:.14 282.89 3.12 348.24 E 333.63 2.35 402.88 E 385.53 0.78 458.77 E 4.38.78 0=92 5t5.4I E 492.8t 0.54 572.96 E 547.92 0.73 631.72 E 604.22 0.87 691.27 E 661.65 0.83 750.5i E 718.78 0.22 809.13 E 775.37 ().43 866.88 E 831.26 0.63 924.59 E 98t.80 E 1038.63 E 1094.79 E 1150.77 E 887. I6 0=06 942.61 0.35 997.74 0.26 1052.41 0.52 1106,,92 0.1! NL SPERRY-:SUN ,, PAGE ":' LINION OIL C:O. OF C:ALIF. G-6 TOTAL D I RECT I ON ANGLE VERT I CAL L. AT I TUDE I EEFTH BEG DEG MIN DEPTH FEET 4000 S 81,8 E 34 4100 S 81,1E 33 56 4200 S 80,9 E 33 37 4300 S 80.4 E 33 4400 S 80,0 E 33 50 4.500 S 80,4 E 34 24 4600 S 80,0 E 34 12 4700 S 79,7 E 34 3 4800 S 75.1E 34 41 4900 S 74,0 E 36 13 5000 S 73,2 E 36 46 5100 S 73,0 E 37 24 5200 S 71,6 E 36 19 5300 S 70,1 E 37 1 5400 S 68.0 E 36 28 5500 S 66,3 E 35 26 5600 S 65,0 E 33 23 5700 S 63.? E 34 26 5800 S 62,0 E 36 22 5900 S 60,6 E 39 2 6000 S 59,6 E 40 47 6100 S 59,1 E 41 38 6200 S 58,0 E 41 21 6300 S 57,2 E 40 47 6400 S 56.8 E 3? 42 3655.63 3738.60 3821,88 3?05.2? 3?88.35 4070,86 4153,56 4236,41 4318.64 43??,32 4479,43 4558,88 4639,45 4.719,29 4799,71 4881,i8 4?64.67 5047,14 5127.66 5205.34 5281,05 5355,78 5430,85 5506,56 5583.50 6500 S 55,2 E 37 16 5663,08 6600 S 55,0 E 36 11 5743,79 6700 S 53,? E 35 46 5824,?2 6800 S 53,1E 34 56 5906,89 6?00 S 52.3 E 34 17 5989.51 7000 S 51,3 E 33 47 7100 S 51,0 E 33 37 7200 S 49,9 E 33 3 7400 S 49.4 E 32 46 7500 S 48,4. E 32 16 7600 S 47,9 E 32 11 7700 S 47.4 E 32 14 7800 S 46,4 E 32 16 7900 S 4.8.! E 29 57 6072,63 6155,?I 6239,73 6323,75 6407,84 64?2.3? 6577.01 6661.59 6746, i4 6832.79 131,65 S 140,29 S 149,04 S 158,24 S I67,9I S 177. ':":' o 187.09 S 197.10 S 211.74 S 228.02 S 245, 32 S 263, 08 S 281.77 S 302, 27 S 324,53 S 347.83 S 371,09 S 395, ?7 S 423,81 S 454, 72 S 487.78 S 521. ?0 S 556, '?1 S 592~ 30 S 627,28 S 661,83 S 695,70 S 730,14 S 764,53 S 7?8,?8 S 833.74 S 868.58 S 903,71S ?38.55 S 973,78 S 1U(..~, 23 S 1044.94 $ 108I. 05 S 1i17.87 S 1151.21 S DEF AR T _IRE FEET B 0 S 8 - 1 ~"-, 'i.".' 8 '?/ MARCH 27.. i982 VERT I CAL DOG CECT 10t',4 L_E:G 1206.36 E 1161.17 0.35 1261.50 E !215.27 0~45 1316.16 E 1268.98 0.34 1370,55 E 1322,62 0.31 1425,39 E 13:76.85 0.42 1481.10 E 1431.78 0.60 1536.45 E 1486.52 0.30 1591.54 E 1541.12 0.23 1646.54 E 1597~45 2.67 1703,33 E 1656,07 1~65 1760.62 E 1715.55 0,73 1818.70 E 1775,94 0~65 1874.90 E 1834.~7 1.37 1931.52 E 1895.08 1.14 1986.62 E 1954,50 1.38 2039.71E 2012.48 !.43 2089.5? E 2067.48 2.18 2140.37 E 2123.~6 1.22 2192.73 E 2183.05 2.22 2247.60 E 2245.64 2,79 2303,94 E 2310.44 1,87 2360,96 E 2376~27 0.9i 2416,98 E 2441,55 0.78 2471.90 E 2505.95 0,.77 2525,35 E 2568,84 1~12 '"'=~=; 06 E ">~":":' 1° 2. A4 2623.43 E 2685.91 1.08 2670.66 E 2742.87 0.77 2716.46 E 2798.4? 0.95 2761.03 E 2853.01 2804.43 E 2?06.57 0,76 284.7,4.4 E 2959,8! 0,24. 2889,16 E 3011,97 0,82 2?30.6? E 3063,85 0.23 2971,79 E 3115.47 0,33 3011.7i E 3051.24 E 3090.5I E 3129.17 E 3166.33 E 3166.1i 0.73 3216,49 0.28 3266,78 0.27 3316.79 0.53 3364,06 2~48 NL SF'ERRY-::~;UN:, INC:. F'AGE._",'-' UNION OIL CO. OF CALIF. G-6 TOTAL DIRECTION ANGLE DEPTH DEG DEG MiN 8000 8100 8200 8300 8400 S 50.4 E 28 43 S 50.0 E 29 20 S 50.1 E 30 47 S 51.2 E 27 38 · =, 51 0 E 27 M' 8500 8600 8700 8800 8900 S 58.5 E 25 1'.:,' S 59.0 E 29 32 S 57.6 E 29 19 S 56.7 E 28 58 S 55.8 E 28 25 9000 9100 9200 9300 9400 S 56.0 E 28 22 S 55.0 E 28 54 S 54.,6 E 2'.~ 50 S 53.9 E 30 50 S 54. I E 31 51 9500 ."Y 6 (.) U VERTICAL LATITUDE DEPTH FEET 6920.48 11,=,i'-'.,.,'::4.:,'-' 7007../_-_,A_ _ 12:17: .7:4. ._,c:. 7 (]'-?:::, .... :, .:, 1.,_94 A_. 17 ._,':' 71,_,~':' ":'. 14.1..."'"' 7.._':"]. 24 ...,c:' 7270.48 I .:,c~4.74 ,_, 7360.88 1327,07 S 7447.88 1352.46 S 7535.07 1378.70 S 7622.56 1405.27 S 7710.51 1432.03 S 7798.50 1458.60 S 7886.04 1486.32 S 7972.78 1515.15 S 8058.64 1545.34 S 8143.59 I576.28 S BOSS- 1 ,,_'-,'.-'.,' 8'.T, MARC:H 2: 7, iS'82 DEPARTURE VER'TI CAL DOG FEET SECT I ON LEG 3203.36 E 3410.14 1.67 3240.89 E 3457.03 0.65 3280.16 E 3506.03 1.45 3316.32 E 3550.70 3.20 3352.74 E 3595.78 0.32 3389.19 E 3638.08 4.27 3431.44 E 3686.90 4.23 3472.79 E 3735.22 0.72 3513.27 E 3782.~0 0.56 3552.62 E 3829.59 0,,71 3592.01E 3876.25 0.10 3631.60 E 3923.54 0~7I 3672.16 E 3772.16 37i3~57 E 4022.10 1.05 3756.31E 4073.56 1.03 :'-i;:l () C~ '-' ='" ,~ ,,,:._, E 4126. ""'; :' .......... , 1 1 3844.06 E 4179.71 0.45 THE DOGLEG SEVERITY IS; IN DEGREES PER ONE HLINDRED FEET. THE VERTICAL .=,EL. T ILN WAS COMF'LtTED ALONG .:, 66._.'::-;'::.~, E BASED UPON TANGENTIAL TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 4179.71 FEET, IN THE DIRECTION OF S 66 53 E BOTTOM HOLE DISPLACEMENT IS RELATIVE TO WELLHEAD. VERTICAL SECTION IS RELATIVE TO WELLHEAD. TRUE NORTH ~~0ob. oo --500.00 --1000.00 --1'500.00 ~sob. oo 2oob. oo 25ob. oo 3oob. oo 3sob. oo Union Oil Comp Our Boss Gyroscopic Survey Job No. Boss-169~9 - Well: G-6 (SEC29 TgN R13W) Trading Bay Un Kenai, ' Alaska ..... Survey D~te: Operator: Ever?tt. Sellers Method of Calculation: Tangential Scale: 1" = 500' 9600 ,-2000.00 HORIZONTF~L PROJECTION 0.00 2000.00 4000.00 6000.00 8000.00 10ooo. 00I, Union Oil Company Our Boss Gyroscopic Survey Job No. Boss-16989 Well: G-6 (S~C29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: March 26, 1982 Operator: Everett Sellers Method of Calculation: Tangential Scale: 1" = 2000' 4179.71' @ S66° 53'E 20bO. O0 9600 40~30. O0 6000. O0 VERT I CF:IL PBOJEC T I ON UNION OIL CO. OF CALIF. G-6 TOTAL DIRECTION ANGLE DEPTH DEG BEG MIN 0 N 0.0 E 0 0 100 N 86.7 W 0 I7 200 N 66.0 W 0 20 300 N 66.4 W 0 40 400 N 85,,3 W 0 31 500 S 78.0 W 0 I9 600 S 83.6 W 0 12 700 N 50.9 W 0 35 800 S 88.4 W 0 36 900 S 84.7 W 0 47 I000 N 89.3 W 0 48 1100 S 88.7 W 0 40 1200 S 68.0 W 0 14 1300 N 84,3 E 1 46 1400 S 77.6 E 3 34 1500 S 73.3 E 6 0 1600 S 72.9 E 9 4 1700 S 74.5 E 11 39 1800 S 82.4 E 13 11 1900 S 85.6 E 15 20 ~d.~O ._. o~.4 E17 45 2100 S 86.9 E 20 55 2200 S 86.8 E 23 55 2300 S 86.7 E 27 3 2400 S 86.0 E 30 9 2500 S 86.1E 32 30 2600 S 85.6 E 33 14 2700 S 85.2 E 34 7 2800 S 85.0 E 34 39 2900 S 84.5 E 35 19 84,4 E 11 ...... · -, -.D/'.:, 3100 S 83.5 E :'-:64.9 3200 S 83.5 E 36 36 3300 S 83,4 E 36 10 3400 S 83,0 E 35 35 3500 S 82,9 E 35 34 3600 S 82,8 E 35 13 3700 S 82,7 E 34 58 3800 S 82,2 E 34 32 3900 S 82,2 E 34 25 NL SPERRY-SUN,. INC. VERTICAL LATITUDE DEPARTURE DEPTH FEET FEET 0.00 0.00 N 100.00 0.01N 200.00 0.15 N 299.99 0.50 N 399.9? 0.78 N 0.75 N 0.68 N 0.98 N 1.28 N 1.20 N 999.96 1,15 N 1099,95 1,15 N 1199,95 1,06 N 1299,92 1,1.3 N 1399,80 0,62 N 1499,43 1,56 S 1598,53 5,38 S 1696,88 10,39 S 1794,53 14,60 S 1891,43 17,12 S 1987,27 19,09 S 2081,60 21,02 S 2174,01 23,11S 2264,25 25.55 S 2352,02 28,61S 2437.43 32.19 S 2521.42 36.12 S 2604.64 40.57 S 2687.~I6 45.39 S 2769.09 50.64 S 2850,24 56.29 S 2930,62 62,57 S 3010,79 69,33 S 3091,29 76,10 S 3172.32 83.04 S 3253,66 90.18 S 3335,19 97.38 S 3417,02 104,64 S 3499,19 112.13 S 3581.62 11~.81S 0.00 E 0.26 W 0.79 W 1.55' W 2.58 W 3,31 W 3,75 W 4,32 W 5,24 W 6.44 W 7.81 W 9.10 W 9.87 W 8.52 W 3.95 W 4,10 E 16,63 E 33,89 E 54,93 E 79,4I E 107,81E 140,84 E 178,89 E 221.83 E 269,58 E PAGE BOSS .... 16989 MARCH 27.. 1982 VERT i CAL DOG SECTi ON LEG O. O0 O. O0 -.0.24 0.29 -0.77 0. 12 --1.65 0.33 -2.67 0.25 -3.33 O. 23 -3,71 O. 12 -4.35 O. 46 -5.31 O. 4.1 .... 6.39 O. 19 ---7.63 O. 09 '8.81 O. I3 -9.48 0.46 -8.28 1 ,, 98 -3.87 1.97 4.38 2.45 17, 41 3, 06 · _,._. ~.._, 2.6i 56.26 2.29 79.78 2.28 106.68 2.43 137,83 3,16 173.67 3.00 214,14 3.14 259,28 3,12 895.74 E 859,,63 0.06 953.19 E 915.32 0.35 1010.21E 970.64 0.26 1066.71E 1025.56 0.52 1122.79 E i080.18 0.11 602.34 E 576.36 0.87 661.50 E 633.25 0~83 720.89 E 690.56 0.22 779.82 E 747.44 0.43 ,...,.-,,,-., ,::,~-)..-:.~ /. o..'.,,c. 01 E 71 ':::~ ...... 321,43 E 308.4i 2.35 375,56 E 359,75 0,78 430,82 E 412.36 0,92 487.09 E 466.03 0.54 544.18 E 520.62 0.73 UNION OIL CO. OF CALIF. G-6 TOTAL DIRECTION ANGLE DEPTH BEG BEG MIN 4000 S 81.8 E 34 ? 4100 S 81.1E 33 56 4200 S 80.9 E 33 37 4300 S 80.4 E 33 29 4400 S 80.0 E 33 50 4500 S 80.4 E 34 24 4600 S 80.0 E 34 12 4700 S 79.7 E 34 3 4800 S 75.1 E 34 41 4900 S 74.0 E 36 13 5000 S 73.2 E 36 46 5100 S 73.0 E 37 24 5200 S 71.6 E 36 19 5300 S 70.1 E 37 1 5400 8 68.0 E 36 28 5500 S 66,.3 E 35 26 5600 S 65.0 E 33 23 5700 S 6,3.9 E 34 26 5800 S 62.0 E 36 22 5900 S 60.6 E 39 2 6000 S 59.6 E 40 47 6100 S 59.1E 41 38 6200 S 58.0 E 41 21 6,300 S 57.2 E 40 47 6400 S 56.8 E 39 42 6500 S 55.2 E 37 I6 6600 S 55.0 E 36, 11 6700 S 53.9 E 35 46 6800 S 53.1 E 34 56 6900 S 52.3 E 34 17 7000 S 51.3 E 33 47 7100 S 51.0 E 33 37 7200 S 49.? E 33 3 7300 S 50.0 E 32 50 7400 S 49.4 E 32 46 7500 S 48.4 E 32 16 7600 S 47.? E 32 11 7700 S 4,7.4, E 32 14 7800 S 46.4 E 32 16 7?00 S 48.1E 2? 57 NL SPERRY-SUN, ItgC. VERT I CAL LAT I TUBE DEPARTURE DEPTH FEET FEET 36,64.25 127.65 S 1178.57 E 3747.11 135.97 S 1233.93 E 3830.24 144.66 S 1288.83 E 3913.58 153.64 S I343.35 E 39?6.82 163.07 S 1397.97 E 4079.60 172.62 S 1453.24 E 4162.21 182.21 S 1508.77 E 4244.99 192.10 S 1564.00 E 4327.53 204.42 S 1619.04 E 4408.?8 2I?.88 S 1674,.93 E 4489.38 236.67 S 1731.97 E 456,9.16 254.20 S 1789.66 E 4649.16 272.42 S 1846.80 E 4729.37 292.02 S 1903.21E 480?.50 313.40 S 1959.07 E 4,890.45 336.18 S 2013.16 E 4972.93 359.46 S 2064.65 E 5055.91 383.53 S 2114.98 E 5137.41 409.8? S 216,6.55 E 5216.51 439.27 S 2220.16 E 5293.20 471.25 S 536,8.42 504.84 S 5443.32 539.41S 5518.71 574.61 S 55?5.03 60?.79 S PAGE 2 B088--16989 MARCH 27. I982 VERTICAL DOG SECTION LEG 1134.58 O. 35 1188.78 O. 4.5 1242.71 O. 34 1296,, 40 O. 3i I :--:~0. ":'.'=-i 0 /,$2 I404.96 0.60 1459.81 0.30 1514.50 0.23 1569.98 2.6,7 i6,27.46, 1,,6,5 1686.53 0.73 1746,.47 0.65 1806.19 1.37 1865.77 t.14 i~25~54 1.38 t984.24 1.43 2040.73 2.18 2096.46 1.22 2154.24 2.:22 2215.07 2.79 2275.77 E 2278.76 1.87 2332.45 E 2344.06 0.91 2388.97 E 2409.60 0.78 2444.44 E 2474.42 0.77 2498.62 E 2538.04 1.12 5673.2~ 644.56 S 2550.20 E 5753.44 678.77 S 2599.25 E 5834.36 712.92 S 2647.04 E 5915.9I 747.33 S 2693.56 E 5998.21 781.75 S 2738.75 E 6081.07 816.36 S 2782.73 E 6164.27 851.16 S 2825.94 E 6247.82 886.14 S 2868.30 E 6331.75 921.13 S 2909.93 E 6415.80 956.17 S 2951.24 E 6500.12 991.50 S 2991.75 E 6584.71 !027.08 S 3031.48 E 6,66,9.31 106,3.00 S 3070.88 E 6753.88 1099.46 S 3109.84 E 6839.47 1134.54 S 3147~75 E 25~9.12 2.6,4 2657.63. 1.08 2714..°'''' 0 ~7 2771~25 0.95 2826.30 0.79 2880.32 0.76 2933.70 0.24 2986.37 0.82 3038.37 0.23 3090.0? 0.33 314i.20 0.73 3191.68 0.28 3241.¢9 0.27 3292,,11 0.53 3:340,72 2.4.~ LtNION OIL CID. OF CALIF. G-6 TEITAL D t RECT i 01'4 ANGLE DEPTH DEG DEG MiN 8000 8100 8200 8300 8400 S 50.4 E 28 43 S 50.0 E 29 20 S 50.1 E 30 47 S 51.2 E 27 38 S 51,0 E 27 57 8500 86.00 8700 8800 8900 S 58.5 E 25 19 S 59, 0 E 29 32 S 57.6 E 29 1':? S 56.7 E 28 58 S 55.8 E 28 25 9000 9100 9200 9300 9400 S 56.0 E 28 22 S 55.0 E 28 54 S 54..6 E 29 50 S 53.9 E 30 50 S 54. I E 31 51 9500 9600 S =;":' 9 E 3:.]: '=/- S P;':' 2 E 33 10 NL SF'E:~RRY-SLfN. iNC. VERT I CAL LAT I TUDE DEF:'TH FEE]" 6926.64 1166.53 S 70i4.08 1197.59 S 7100, 61 1229. "- /.Z' S 7187.86 1260.71 8 7276.32 1289. ?9 S 7365.69 1315.¢i S 7454.39 1339.77 S 7541.49 1365.58 S 7628.82 I391.99 S 7716.54 1418.66 S 7804.52 1445.32 S o~.~,=, 1472.46':'..., 7979.42 1500.73 S 8065.73 1530.24 S 8151.13 1560.81S F'AGE BOE;S- i 6'? 8'.:? MARC:H 27.., i i;'82 DEPARTI IRE 7ERT J: CmL. DC,] FEET SECT I 0 I',.i i__ E('S 3184.85 E 3387, 37 1,67 '-' .... "-' '-' 3433. :::.-: 0 /-, 5 ,:.~.~., 1..:, E ....... . 3260.53 E 3481.76, !.45 32 t:,/8.24 E: -:, =; -?,:, =; c, :3 ~ 2 <] 3334.53 E 3573, 43 0,32 3370.97 E 3617.10 4.27 3410.32 E 3662,65 4.23 :--:452.11 E 371 i, 21 0 .~ 72 3493.03 E 3759,20 0,56 ':' 5':' ":' '- =':3 8 0 6 ......... ~...~._, E . :37 0,, 71 3572.32 E 3853.03 0. I0 3611.81E 3899.99 0.7i 3651.88 E 3947.93 0.96 3692.86 E 3~97.19 1.05 3734.94 E 4047.88 1,03 ]'HE DOGLEG SEVERITY IS IN DEGREES; F'ER ONE HLINDRED FEET.. THE VERTIF.'AL_ :=,E_. F ION WAS COMPLITED ALONG ._,':' 6/_-, ._Pi':',.;;, E BASED UPON T'RAF:'EZOIDAL TYPE CALCLILAI'IONS. ]'HE BOTTOM HOLE DISPLACEMENT IS 415:3, 1:3 FEET., IN THE DIRECTION OF S 66 58 E BOTTOM HOLE DISPLACEMENT IS RELATIVE TO WELLFIEAD. VERTICAL SECTION IS RELATIVE TO WELLHEAD. -50b. O0 TRUE NORTH. --500.00 --lO00. O0 --1500.00 I ~oob. oo ~5ob. oo Job NO. Boss-16989 Well: G-6 ( Trading Bay Kenai, 'Alaska . _ Survey Date: March 26, 1982' Operator: Everett Sellers Method of Calculation: " ' ~-'~~~',.. 00 Trapezoidal Scale: 1" = 500'' --2000.0·0 HOBIZONTRL PROJECTION 0.00 2000.00 4000.00 8000.00 8000.00 10000.00~ Union Oil c~any Our Boss Gyroscopic Survey Job No. Boss-16989 Well: G-6 (SEC29T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: March 26, 1982 Operator: Everett Sellers Method of Calculation: Trapezoidal Scale: .1" = 2000' 4153.13' @ S66O 58'E 9600 20bO. O0 40~0.00 60~)0. O0 VERTICIqL PROJECTION April 19, 1982 Mr. Gary Bush Union Oil of California P. O. Box 6247 Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. Boss-16989/16006 Well: G-6 RD (SEC29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: April 17, 1982 Operator: Everett Sellers Mr. Bush: Please find enclosed eight (8) "Originals" and fine (5) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. This survey is a combination of Boss gyro data from Job No. Boss- 16989 dated March 29, 1982 and Job No. Boss-16006 dated April 17, 1982. Each folder presents the survey in Radius of Curvature, Average Angle, Tangential, and Trapezoidal Calculations. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures 9£'CEIVED JUN 1 4 982 Afaska Oil & Gas Cons, Comrni$$io/~ /~nchorage ,r.'ERR Y -. ;::, ..IN WF[ I SURVEY i NG COMPANY F.~A(:;E i '~'' ::: ANCHORAGE: ALASKA :: '; :: ~ E:tJRVEy : ALASKA KELLY ~USHiNG ELEV~ = '?'?~00 F'T'~ OPERATOR-SELL. ERS ~ON::CALCULA:TED:. ALONG CLOSURE : : I3EF:'TH DEPTFt DEPTH DEG M I N DEGREES DEG / 10C~ NORTFI/SCILI]"H EAST/WEST SECT I ON ::::::::::::::::::::::::::::::: :J,::.-...:~O:::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::: :::::: :::::: ¢ t~:~: ~:::./:::: i :N: L.". ~:..-. 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JRVE'¥ lNG C:OIdPANY PAGE 7 j;: ,;:~%,:~;,:~::~:;::~ :.: : ~ ::;: 2 :::: : :; :; : ..... ; . C~PE:RATOR-SEL. LERS MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPT'H DEF"TH DEPTH NORTH/SOUTH EAST/WEST D I F'FERENCE CORRECT i ON :::::::::::::::::::::: :::::::::::::::::::::::::: :::-?:~: :~.: i::~ ::~: :,~.::: 3: :::::::::::::::::::::: ::; i:::i ::: :~ :~ ~:::: ~ :::: :: :: ~ ~ ~- '~' n ~' 2227 2i99.00 2100.00 23~74 S 190.19 E 28~34 8.74 2:3:39 2299.00 2200.00 26.64 S 2:39.98 E 40. Ii I1.77 ::: :::::-23:9'F'-~:00 ::.: 2:Ex}O:, 00 : ~30,52: S :: ~ 297, ~J: E - 55- :36 15.25 2936 2799.00 2700.00 52,66 S 565,23 E 137.50 3060 2899.- 00 2800, 00 59, 87 S 6:37, 93 E i 61,34 : :.:: :.~¢ ~.- z: ~:~:~:.:.: ::,:~ : : ,~1 .~1 :: ,~!~::~ : ~.~:.,~ 3677 3:i:99. O0 3300.00 103.02 S 997.68 E 278,, 86 3799 3499,,00 3400~00 I12.09 S 1066.54 E 300.62 22, 26 2:3.84 24.82 24" 23 23.26 .,::..:,, :22 21.76 2i. 29 2() SPERRY-SLIN WELL SLtRVEYiNG COMPANY F:'AE~E ' U:I~... -,..,U, :L,F L,¢~LIF, :: : DATE GF E;URVEV AF:'RtL. i7, !5;'82 ::: TRAE~iNG: BAY LtlgZT ' APIRIL AL. ASKA KELLY E:USI..I :[ NO ELEV, OF'ERATOR : : :: ::: . :: : :: :: 'i :: : :::: : ' : : : : : : : : : : : :::::._:; :::: :: :..~ :. :: TRLiE NEASLIRED VERT i CAL VERT I C~L RECTANGLiLAR COORD ~ NATES HO- ]'VD VERT Z CAL DEPTFi DEPTH DEPTH NOR]'H / SOLITFI EAST/WEST D I F:'FEREI~CE CORRECT I ON 4765 4299. O0 4200. O0 19':2./i, 2 S i599.94 E 466,. 18 4E:87 : 4399,0(~ :4:300,00 : 2i7.8:3 S E] 488~44 ....'=.,:.":: /...., .,., 4. ,'.',._ '.:7,'. 9. ,, 00 4600 ,, 0 C;, 2:34- ,,, _'i 8 S 1 ,,':',_,':' .I. , ,:,": <, '"'' E S'.':: ~:I/-, 47'? 9 0 O 47 Fi ¢') 00 310 44 ':' ]. G'?; i '"" =:':: ! C~ 4899,00 zi.c:C,O, O0 .o'-"-"-':::,,:, ...'9:',_, ._,o .~::.,:,(:, ~.o., · ,.:, = 69 g 56:i:! 'R~;:-"9, O0 A:'F'O0,~:O0:366:" 6'7 ; 20:30;,:: :19 E :::':,2 :,:e:.'e :OCi :500c.~. O0 :: F;!:,//:,, A';': :: 2i 4-I::" :A4: · z,b :// Fi 199.., Of) =: i Cxi:,:, O0 4"-:;/, 35 '..5.'; .~ ....... 6007 5299. O0 5200,, O0 47:i:,, 71 S 2280,, 02 E 6140 =' ""-":'/ .... '"'" = = · ..,.z, .:- :. 00 N 2 (')(). 0 O :7., -t ,'", '7'::' ........... :,. ..... ::, .¢:..':,oo. 70 "'-'"'~'-' - . ....... '74 'q ¢~; 0 ,:.z.: ,:. 54,95>, O0 540(}, 00 PiAF'~, 3t S ........... ,.., E 6404 : ~.Hi:.)9~C~O: : Fi.=;Cx}. O0 6IJ,, 50 S ,~:,,,,c i:,:z..~.: E: 562.77 6 i 'i ~ :30 632.03: /-,5::: 19 678 ,,,_,'::' .:.,"':' 708= 4 J. '741.66 774.7~ 20 .,, 50 20 . 03 20,, i l · '::' ('~ 88 20. '77 2 0.86 22 ,, :27 ~:',,, :}}8 25 ,, 55 24= 39 .... ' 3. F:i 5 20.7:3 2 J, ,, I/2, :25,, :t 4 · ';) ('i ¢% :2:3 ,, () 5 Si. 17 SPERRY-SUN WELL SURVEYING COMPANY PAGE :::7' :;"::~::: : :':~'~:::::"::: :- :: : ~ ANE:HC~RAO:E AL.A:F;f'4A ::: : :: n~:~:rE F~F: ,:'t ~R'UF:'¥ AI::'P T/ *i "'~ ":;'::'":' t~" :::'~:: .: :::::::::::::::::::::::::: : :. : ~.~,, ~ ~. ,~-"..~ .... ~ ...... / ~ 1 LIOB NLJIgBER BC:,E;S'~:,989/16006 ALASKA KELLY BUSHING E;L. EV. = 99.00 OF'ERATOR-SELLERS P'ESASURED VERT Z CAL VERT Z C~L RECTANGULAR COORD Z NATES MD.¢.TVD VERT Z CAL DE., , 1 ~ DEF:'TF1 DEPTH NORTI'~/SOUTH EAST/WEST DIFFERENCE C:ORRECT :I: ON ::: ::: :~::: :: [~;:: : ~:::::~:~ i~ : :~::::: 6900 5999.00 5900.00 782.00 S 2739.:t, 4 E 90t.70 21.59 702i 6099.00 6000.00 823.78 S 2792.06 E 922.:30 20.&l 7 & I 6 F.~ g";' ~ 00 65 O0.00 10:3:3.0:3 S :30:38, :~ :3 E 1017, 62 i 8.2 i 7734 6699. O0 660C). 00 1075.58 S :3084.64 E I035.83 18.21 ,:~,799.-00 6700~, 00 i i 18~ 74 'S 3. i30, '29 E ].053.94 18. i i :::: ::: i::l ~-::z:~ L, 7:: ::a,:::: ::: .:~ z: :l: 5 :,: ,:, ~: E.: iOc,.:,~ 4o i 4 rE;E: ! 2 7 i 99. O0 7 :I. 00. O0 ! 264, 30 S 3302.77 E J. ], I 3 ~ 2~E; i 4, 44 8425 7299.00 7200.00 1297.21 S 3343.84 E Ii26.29 i3.0i o~J.j,e, /,;7~0(.~;; ()..1 : i,z,.a4; c,:/ .:~ c,o~z,.. u:~ ;~E l t:.z, 7- to i I, 47 · .:,FEP(N~ -c, dN WELL SURVEYZNG COMPANY PAGE: .... TRAD ! NG o ~ , .. ~.,,,. , z:,~.~Y LIN I T APR I L I"F', :I<;'':'':' ,JOB NL.iMBE/R BCISS';'~' i 6'~;:f:?/i 6006 A L A SKA KiiE L L_ Y B LiS H ! NG EL EV. OPERA TOR-E; ELL ERS : ~I= ~,':'~ ~c,~'n VERT l CAL VERTI P~ .... ~--, ......... s~. ...~L REC:TANGULAR C:OORD Z NATES ND- T'VD VERT I C:AL DEF:'TH DEF'TH DEPTH NORTH/SOUTH EAST/WEST D i FFERENCE CORREC:T Z ON :: o ~ o.J :7o:,:. O~J 7c,00. O0 : ' i:,,:,o -,~,, ,:,e. :,:,: c;.47 r/,::l ::z E 1 :~ 6~z, ~ .50 :: 14.64 :: :,ox ;. o;. :: -.~., O: z ~,(~d:. ~:j~.) ,,~, ::[ I 1,~,O./-,~: i4.12 -: : : 897~I: : ::: 7:7'P'P;,~ O:G : 77P0~ O0 ~:: t ~:J~::,' ' ~x::~ ~ ".S ;~5e, 7'~ t:: t':': ':: E ......... ~?:?: zi.. ~'~ ~ 1" '7!~ 9(3'T; 9 7 A 99 00 ~'-' - ' ....... :,; S :3604 30 E ~'?00 ~7 7 77' ?204 7'~9'~; O0 7900. O0 ~4b'~; :'::9 S '-" "~'~ '"]~- 4 ?7 'F'307 ':'qq'~' 00 A('x:x'~, O0 148 ]. -"-' S ,:'/- ::,~ /-,9 E 1208.47 :3 33 . : ';/40'~': : ' :~:i,::/':) .,nO ~':~nO :0(~) : : z c;. F?"~ rE; :.?~ ::: : o;0::,~ . .?:::: :: :: :::::?f~.::l:~:~: : :::: ~].,_.~2~'~'9:~ (~:i:,:.. ~:: : .: .:,, .:..~i:: : I z~'~,77L. :[... .~, :':i~F q':l: ~ P~/.: ::F]: :. :::~::,q: :: .,;.c' ,, Fi_ :3 ................. ;;c,-l-~:, ,:,'c~-Y';~-O(:~ .... o;.:~t~L-) ~'t)~) ...... i. ~-~(-),--4. ~ ;-, ......... : ,7~ l~, ',~,' ~ ......I :,:' t ~,,':', ~ :3.0'~? ' 'F' 7 1 8 ,:, ~ ;. ;. 0 0 8 4 0 0.0 0 1 5 0 F:. ' :~ ~':' ":' 4~ S :3744 E i i9 08 2 71 ? 820 :q 599 00 :::: ~100.00 i ':' 9 ' '-"~' = ' - ':,":, ....... :, / e, ._, . e, ::: E i i :3t .. :. j)o : eTO0: PO :s: :E i 4s i - 4:3 ....... : ..... :-:-:!~Z5 ............. :::~:~'57:~::00 ........ :::Ot~:O0:~, 00 ........ · ::-:: 1:515~55::-S . ======9============+ E== .... .... :1:22:6:, 6:3 O. J. (3:326 '~'07'::. C,O 'F'O00. O0 t:'._ 17. i:;e:, S 3842. 'F/1 E I:zz7.- -" 50 O. 87 ~0427 'Pl':?9 O0 'PiOO O0 I51'~'.S72 S ""'"'~$~ 30 E I228.29 0~79 : Z:_ ~ . :: _,__L: ::~:: _ Z: : .::.:. 2:: ~:. _.::~Z : ===================== 2:: _J ~: :LL: _:::: . :: : :_ :::: : : : 'j. 0 ::. :::::::::::::::::::::::::::::::::::::::::::: ===================== :::::::::: _;:::: ::: :: : . . SPERRY-SUN WELL. SURVEYING COMPANY PAGE I1 ."'- ':~: i i'~ NCHE~R-A]:.iE :AL. ASKA:::' : : L 7, : -:: ::: :::: :::: ': : ::::: NUMBE~ BIDSS' ! 6'?"E~'?/16006 ALA'SKA KELLY BUSH INF: ELE'V. := '?'P.O0 FT,, OF'ERATOF.:-SELLERS :.::::: < :: ::?: :: :: :::: ,: :: ::: ::- :::: :: ::: : :: :::: : : : : ?iEAL--;URED VERT:CAL VERTICAL RECTANGULAR C:OORD I NATE::3 i""tD- TVD VERTICAL :OEPTH DEPTH DEPTH NORTH/SOUTH EAST / WEST D I FFERENE:E CORRECT I ON :.:::::::'::: :::: :7: : : ::::::: ::::: :::::::f:: ::::: : : 7:' :::7~:7: : ::: : :::::::::::::::::::::: i+?:: :::::::: ::~:;~:~,.?.~::: ~;~':,:: :::; .~;-".,,i~ ::&:i":,::: : :: ,., , ,,~c,::i: :~=~::::::::::::::::::::::::::::::::::: ::~ .,:~.:? $ ~, :,=,o:::::: :: i, ,.:,,'.:, ::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: ::::::: i~i~::ff::'. :::::::~::~,:: :: ::: :::::::::::::::::::::::: ::::::::::::::::::::::: ':: :~i:~ :::: ::: ::-;.;~?i::::'.'ti:; : ~ - :" .......... ......... ========================== :. :: :I.,.'-::c,:..':,,:,, ;-~::i: :::' ,:,, :t:236;; E~O :. :: 2: 1 1000 'P74':,2 ,, ,.:,7 'P,.':,6:3 ,, 67 1518, 51 S .3'~.754 ,, :3 i E 1237, :3:3 1 ,, :3:3 -50~.00 TRUE NORTH ,, --500.00 --1000.00 --1500.00 ,-2000.00 ~oob. oo ~sob. oo · Union Oil-of ~lifo~ia O~ ~ss ~roscopic S~ey Job No. ~ss-16989/16006 Well: ~6 ~ (S~29 ~N R13W) Trading ~y Unit Alaska , · .......... ~.Kenai S~ ~te: ~ril 17, 1982 ..... ~erator: ~erett ~llers Sc~e: 1" = 500' Meted of ~lc~ation: Radi~ of ~t~e HOBIZONTRL PROJECTION O. O0 2000.00 Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16989/16006 Well: G-6 RD (S~C29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: April 17, 1982 Operator: Everett Sellers Scale: 1" = 2000' Method of Calculation: Radius of Curvature 4000.00 6000.00 8000.00 10000.001 4236.32' @ S68° 59'E 2o~o. oo 4o~°. oo VEBT I C~L 60~OO. OO P R C~ J.E C T I ON LtNION OiL CO. OF CALIF. G-/f., RB TL-fTAL B I RECT I ON ANGLE DEPTH DEG DEG MiN ¢:.~ N 0.0 E 0 0 i00 N 86.7 W 0 17 200 N 66.0 W 0 20 300 N 66.4 W 0 40 400 N 85.3 W 0 31 500 S 78.0 W 0 1':? 600 S 83.6 W 0 t2 7o0 N 5o '~:' W o ':'~ 800 S 88~4 W 0 36 900 S 84.7 W 0 47 1000 N 89.:3 W 0 48 1100 S 88.7 W 0 40 1200 S 68.0 W 0 14 I300 N 84.3 E 1 46 1400 S 77.6 E 3 34 1500 S 73,,3 E 6 0 I600 S 72.9 E 9 4 I700 S 74~5 E I1 39 I800 S 82.4 E 13 11 1900 S 85.6, E 15 20 2000 S 86~4 E 17 45 2100 S 86.9 E 20 55 2200 S 86.8 E 23 55 2300 S 86.7 E 27 3 2400 S 86.0 E 30 9 2500 S 86.1E 32 30 2600 S 85~6 E 33 14 2700 S 85.2 E 34 7 2800 S 85.0 E 34 39 2900 $ 84~5 E 35 19 3000 S 84.4 E 36 11 3100 S 83.5 E 36 49 3200 S 8:3.5 E 36 36 3300 S 83.4 E 36 10 :3400 $ 8::::,, 0 E 7:5 35 3500 S 82.9 E 35:34 3600 $ 82.8 E 35 I3 ::.".-':700S 82,, 7 E 34. 58 3. 8. 0,3. 8 ,,,.,'::',.,:~.":'. 2 E :34. :'::~ 2 3900 S 82.2 E 34 25 VERT i CAL [,.AT ! TUDE DEF'ARTLiF,;E DEF'TH FEET FEET O. O0 0. O0 N 100.00 0.01 N 200.00 0.!4 N 299.99 0.5() hi :399.99 0.75 N 0.0,0 O. 2/_-, 0. ;30 i.60 :2.6,1 999.96 1.03 N 8.00 1099.95 1.02 N 9.28 1199.95 0.86 N i0.05 1299.93 0.83 S 9.63 1399.82 1.10 S 4.~ I499.48 3.20 S 3.09 i598.61 7.01S 15.63 1696.99 12.05 S 32.88 1794.64 16.36 S 53.95 1891.56 18~93 S 78.45 1987.43 20.92 S 106.85 208I~79 22.85 S 139.9'0 2174.24 24.95 S 177. ';'6 2264.51 27. :39 S 220.91 2352.31 30.44 S 268,68 24 ::37. -/. ":' S' 4. 0,2 S :':: 2 o P: '=' 252 !. 7:2: ::::7.94 S :374.67 2604.95 4.2.39 S 429. ':74 2687.47 47.21 S 486,,21 2769.40 52 46 S F4 --, .... 4.:,, :31 2;::?]0_ _.. ,_,.,=i=' 5;R_. I I S 601 ,,, 2930.93 64.38 S 660,,62 3011.I0 71.i5 S 720.01 309 i. 61 77. '..:.:.'2 S 778. 'PS :B :I. 72... 64 84 . ,:,"-'.., ''='' ._,c. 8 :B'.7. i ,4 F'AOE I A F'R l L 17, ! "::;:8:2 VERT i CAL L:; E C T ]: OIq L. E G 3335.50 99~20 S 952.32 :B.4 .I. 7. '::'":' 1 "/: t, .:, 4.6 S i C.'09:34, ::::499,, 50 i 13.94 S 1065,, 84 358! ,.. 94 !21 ,, <'::,3 S ! !2i. '.:.;'2 E W W W W 0. O0 0.0 -0,, 24. 0 :, 2-'-': -0. '79 0 ~, I -i. ,i'..7 0._, :.33 .... 2.70 0,, 25 W W W W W -. 3.._,':' ,_,/- 0 ., 22: - :.7.; ,, 76 0 ,, i 2 -4-,, 4:3 0,, 46 -._,. 46 0.4 :L x F;/-, () ~ 5:: ! 07.24 2,. 43 i38.77 3. i6 17= "~- ¢ ._,. 0..:, :3.00 216,, 02 3. 14 26 I. 70 :3 ~ i 2 31 ! ,~ 35;' 2 ,, 35 :':i:63,, 32 0 ,, 78 416.50 0,,, 92 470.75 0,, 54. 525.92 0 .., 73 E 868,, 24 0,, 06 E 'P 24.4,'!, 0 ,, 35 E 98 C, ,, 2:::70.2:6 El 10:3 5. '70 0 ,, 52 E: 105;'0,,. 80 0 ,, i i LJNZON OZL. CO,, OF CALZF',, G-6 RD TOTAL D I REL.. i ON ANGLE Ii. EF TH DEG DEr~ M i N 40()0 S 81,F: E 34 410C, 8 81.1 E 33 56 4,200 S 80,,':7..' E 3:_,' 37 4300 S 80.4, E ..:,'-"-'.:, 29 4400 S 80,, 0 E 33 50 4500 $ 80.4. E 34 24 4600 $ 80.0 E 34 I2 4700 S 79.7 E 34 3 4800 S 75. I E 34 41, 4900 S 74.0 E 36 13 50(}0 S 73.2 E 36 46 5100 S 73.0 E 37 24 5200 S 7.1,. 6 E 36 i'.:.) 5300 :=; 70. 54(}0 S 68.0 E 36 28 .=, o,.,. 0 E :33 ":":' 5700 S 63.9 E 34. 26 5800 S 62.0 E 36 22 5900 S 60.6 E 39 2 6000 S 59~6 E 40 47 6100 S 59.1 E 4,1 38 62(}0 S 58.0 E 41 2& 6300 S 57.2 E:: 40 47 6400 S 56.~-q E :39 42 6500 S 55.2 E 37 .1.6 66(.',0 S 55~0 E 36 lZ 6700 S 53.9 E 35 46 6800 S 5:9.1 E 34 56 6?00 $ 52.3 E 34 17 7000 S 51,,3 E :33 47 7100 S 5&.O E 33 37 720(:, S 49.9 E 33 3 7300 S 50.0 E 32 50 7400 S 49,,4 E 32 46 7500 S 48.4 E 32 16 7600 S 47.9 E 32 I~ 7700 S 47.4 E 32 ~4 7800 S 46,,4 E 3:2 i6 7900 S 48.~ E 27 57 NL 5;F'ERF;,'Y-SUN) ~ NC,, VERTi CAL LA7' I TLiDE DEPAF~TLIRE DEF'TH FEE7' F'EET 4 ! 62, 53 i 84, 03 S 1507. '? 1 ti:--. 4245.31 !93.92 S 1563.13 E 4327.85 206.2:3 S 1618.22 E 440. 9., ._,':' 1 Z 2: I ,, 69 :::; 1 o 74 ,, t :3 E 4489.71 238.47 S i731. i7 E 4569.49 256,,00 S 1788.86 E 4/-,_ 4 '-?. ~ 50 27.:I. .2 .'-I. ._,c' i ,::, 4 e, .00 E 4729 70 ':'q"::' ,':3:F~ c. ,: ......... 1 ':"']":' 4.2 E 4809, 84 3.1. 5.22 S 1958, 28 E 48~0.79 338.0! S 2012.38 E 4973.28 36i.32 S 2063.87 E 5056~27 385.38 S 2114.2~ E 5i37~77 411.73 S 2i65.81E 5216.89 441.10 S 2219.45 E 5293.5? 473.08 S 2275.07 E 5368.82 506.67 S 233&.75 E .__._._,~44':', ?">.~. !~41_ , :24 S =.':,.:,,:,o.., ,_, ,_,.._77 .E 5519.1i 576~44 S 2:443.75 E 5595.43 611.63 S 2497.93 E 5673.72 646.42 S 2549.51 E 5753.86 680.63 S 25~8.56 E ~'-'"~ 79 '-'~ ' ,.,:,o4 7:[4. 79 S :36 E 5916.34 74~.2I S 2692~87 E 5978.64 783.63 S 2738.06 E 6081~50 818.24 S 2782.04 E 6164.7r~ '::'~]':' 04 S .::,c,,-,~ .-:,.=; F 6248 '-":- J.z, S . ~..:, 888. c '~' 2867 ,, 6 ~ E 6332~18 923,02 S 290'?,24 E 64i6~23 958.06 S 2950~55 E 6500~55 993.40 S 2991.06 E 6585. i4 i028,,98 S 3030~79 E ,'::., 6 6':::' ,., 74 1064.,, 89 S 3070,, I '.:.-;' E 6754. :31 110t,,36 S 3109. i6 E ,,::, o :.. = '.::;'7: i 1:36 ,, .4:3 $ :'i: ! 477 ,, 10 E · PAGE .,::"" BOSS- i 698'.:,:/I ,'_:,00,!, APRtL i7:, .I. 982 V E R T I C A L D 0 S E C T I Ct N L E G 1 i 45, 68 ,:":,. :35 ! 200.. 34 C;,, 4.5 '-'.~] 4 70 0 ,, ':' 4 1308: :~: ! 0. :3 J. i :36:3: i 8 0 ,, 42 170!.39 0.73 176i.53 0.65 I821.41 i.:B7 1881. I0 I:i4 1940.92 i.38 199'.:;'. 5'.:;' I ~ 4 3 2056,, 02 2.18 2111.64 !. 22 2169,, 26 2~ 22 2229~86 2.,79 2293,, 26 I. 87 · -:;, .:, ~ o .-,,--, 0 ,. 9' ], :2 4, :2:3 ":":' C' 7"'::' 2487= 7".-'.> 0 ,, 77' .~.._, .... 1 00 ~,12 261 I./':',3 2 =/34 2669,, 69 !., 08 2726.56 O. 77 2782.33 0 ,, '.::;'5 283/3.87 0 ,,, 79 3 i 4. 8 ,, 31 0.7:3 3198. 1,6 O. 28 :3247,, 82 O, 27 32!.:.:'7 ,, 280 ~ 53 334.5~ 28 2,, 4,8 NL SPERRY-SUN., L!NION OIL C:O. OF CALIF, (3- 6 RO BOSS-' i 6'!.:":E:'i;' / j. 60,06 APRIL 17.. i $82 TOTAL D I RECT i ON ANGLE VERT i CAL LAT i TLiDE DEPARTURE VERT i CAL DEPTH DEG DEG M I N DEPTH FEET FEET.' SECT I CIN 8000 S 50,,4 E 28 43 6927.10 1168.41 8 S'184.2i E 33',71.40 8100 S 50.0 E 29 20 7014.54 11'.;.'9.47 S 322't. ,, 49 E 34.'}.:7. :..-..:5 8200 S 50.1 E 30 47 7101.08 1231.64 S :B25':7.'.90 E B484,,74 8300 S 51.2 E 27 38 7188.36 126,2.59 S 32':.-.'7.64 E 353I ,, 08 8400 S._.=; !. 0 E 27 ._=~ 7 7276.82 12.. 9. 1 . ,_,':,'7 ...... S ::~ ::~ ::~ :::~ 9 :B E ..:,"" ._, ~'- '-"., .J ~' . 46 8500 '"' ~'" ":" ~ 7366, 21 1 :B 17.74 ::, · : ..... :,.5 E .... 19 . ' .... :B370.54 E :B618.'91 c,~:,ou S 59.0 E 25' :32 7454.97 1341.63 S :B40'P.9~ E 3664.23 ,:,~r~r~ =; 29 ';' ~ ~5 ~'-' 07 1 ':'/- 7 44 S '~'4 =~ i 70 E ::: 7 c, .... z ...... S ... 7 .6 E ., I . z ......~: ...... ._, _,. . ~ ....... .. 1 .,:. ,, 5 .i ,:,,:, q., 0 ,:,~ ~,. ~,:: .... ' '-' ''~ ._, ..._,. :B 492. F ':' E "~ .... . ~ 18 :q 900 S ._ 6 :B E "~'-' 20 771 '7. i 6 1420. "" '~' .::,:, . .:,.~ S 60 E :B 807 00 8950 S 60.0 E 25 54 7761.66 ~432.:35 S 3551.76 E 3829~38 ~000 S 6,4.2 E 23 34 7807.07 1442.14 S 3570.45 E 3850. Z5 9050 S 67,,0 E 2I 52 7853.19 I450.~ S 3588.03 E 3869.43 9100 8 64.9 E l? I7 7900.00 1457.28 S 3604.08 E 3886.?8 9150 S 6,4.2 E 17 44 7947.41 I464.10 S 3618.4t E 3?02.80 9200 S 6,2.2 E 16 10 79~5.23 ~470.67 S 363i.42 E 3917.30 9300 S 60.6 E I3 14 8091.~6 i482.82 S 365:B.7~ E 3942.47 9400 S 6,4.7 E 11 13 8~8~.69 1492.55 S 3672.5i E 3763,,51 9500 S 81.6 E 1:3 54 8287.2~ ~498.85 S 3693.32 E 3985.~? 9600 S 82.7 E ~4 8 8384.31 1502.~6 S 3717.32 E 4008~78 9700 S 82.6 E 12 41 8481.59 1505.12 S 3740.32 E 403i~3i ~800 S 82.4 E 11 4~ 8579.33 t507.88 S 3761~24 E 4051~83 9900 S 82.2 E ~0 5 8677.53 1510.4~ S 3779.~4 E 4070.~? ~0000 S 82.8 E ? 26 8776.08 i5~2.62 S 37~6.75 E 4086,,67 10100 S 81.7 E 8 39 8874.84 ~514.74 S 38~2.33 E 4~01,,~7 ~0200 S 79.0 E 7 37 8973.83 1517.11S 3826.28 E 4i~5.84 10300 S 79.6 E 7 29 9072.~7 1517.55 S 383?.20 E 4~28.78 10400 S 81.5 E 7 3 ~172.~5 152t.63 S 3851.68 E 4141. i7 I0500 S 82.6 E 7 22 727t.36 I523.37 8 3864.1I E 4~53.40 10600 S 85.4 E 8 4~ ~370.36 1524.84 S 3878. i1E 4i67~00 t 0700 N 87.4 E: i0 43 '?.'468.'9I 1525.13 S 38'95.08 E 4i82.94 10800 N 85.6, E 11 36, 'P567,,0I 1. 523.95 S 35'14~40 E 4200:,55 .... o ~, '~ 664 97 1 ?,'::' 9 41 :~.; .t. 1000 N 85, 6 E i 1 36 97/-,2, 93 1520, 87 $ 3954,, 4'.:.:' E 42:36~. 8,':, LEG '2 '7 2::::: 72 56 5. 'Pl .5~ 83 4.05 !5,, 35 3~i5 !~46 i ~ 00 i ~ 60 0,, 6,5 0. :'.']:! I. 10 0,,15 O. 50 O. 35 1.50 ~:,, 26 0 ,, 95 0,~ 00 0.00 THE DOGL. EG SEVERITY IS IN DEGREES F'ER ONE HLINORFZO FEET.~ THE VERTICAL SECTION WAS COMPUTEB ALONG S 68 58 E BASED UPON AVERAGE ANGLE TYPE CAL. CULAT!ONS. THE BOTTOM FiOL. E DISPLACEMENT IS 4236.86 FEET~ IN THE DIRECTION EiF' :...-.,; 68 58 E BOTTOM HOLE DISPLACEMENT !S RELA]'iVE TO WELLHEAD,, VERTICAL. SECTION iS RELATIVE TO WEL, LHEAD~ -50~.00 , ~-~L__~~ ~oo~. oo ~so6. oo~oob. oo~sOh. oo~oo6. oo~sob. oo ,. --500. O0 --lO00. O0 Union Oil of ~lifo~ia ~ ~ss ~ros~pic S~~ Job No. ~ss-1698 Well: ~6 ~ (S ~adzng ~y --1500.00 --2000.00 TRUE NORTH Kenai, Alaska Survey Date: April 17, 1982 Operator: Everett Sellers Scale: 1" = 500' Method of Calculation: Average Angle HORIZONTRL PROJECTION 0.00 2000.00 ~000.00 8000.00 8000.00 10000.00, Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16989/16006 Well: G-6 RD (SEC29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: April 17, 1982 Operator: Everett Sellers Scale: 1" = 2000' Method 'of Calculation: Average Angle 4236 86' @ S68O 58'E ~ · 11 oo0 ~o1~o. oo~o1~o. oo ~obo. oo VERTICRL PROJECT I ON LINtON OIL CO. OF CAL. IF. L-o RD TOTAL D I RECT I ON ANGLE It-I'" DEF'TH DEG [ ,:. _~ M I N 0 N 0.0 E 0 0 I00 N 86.7 W 0 17 200 N 66.0 W 0 20 300 N 66.4 W 0 40 400 N 85.:3 W 0 31 500 :-:: 78.0 W 0 19 /_-,0C>. S ,_,o.-.,._,. 6 W 0 l'-'z. 700 N 50.9 W 0 :::5 800 S 88.4 W 0:36 '.':.'00 '.S 84.7 W 0 47 1000 N 89.3 W 0 48 1100 S :=:8,7 W 0 40 1200 S 68.0 W 0 14 1300 N 84.3 E I 46 1400 S 77.6 E 3 34 1500 S 73.3 E 6 0 1600 S 72.9 E 9 4 1700 S 74.5 E !I 39 1800 S 82.4 E 13 tl I900 S 85.6 E I5 20 2000 S 86.4 E 17 45 '? 1 O0 S '-" ...... ::,o.9 E 20 55 2200 ,:-. - ,:, o.-, ~ .... :. HA. E ~'?:~00 .... S 86.7 E 27 .=,'-' 2400 S 86.0 E 30 9 2500 S 86.1 E 32 30 2600 S 85.6 E 33 i4 2700 S 85.2 E 34 7 2800 S 85..0 E 34 39 2~00 S 84.5 E 35 19 3000 S 84.4 E 36 1I 3100 S 83.5 E 36 49 3200 S 83.5 E 36 36 3300 S 83.4 E 36 10 3400 S 83.0 E 35 35 3500 S 82.9 E 35 34 3600 S 82.8 E 35 13 3700 S 82.7 E 34. 58 3800 S 82.2 E 34 32 3?00 S 82.2 E 34 25 NL SPERRY-SL1N, INC. VERT I CAL LATi TLIDE DEPARTLIRE DEPTH FEET FEET 0.00 0.00 N 0.00 I00,00 0,03 N 0,52 200.00 0.2'7 N 1.06 299.99 0,, 74- N 2,, 13 399.99 0.8i N 3.03 499.98 0~70 N 599.98 0.66 N 699.98 1.30 N 799.97 1.27 N 899.96 i.i4 N :3.9:--~ /4.7t 5.76 7.1i 999.95 1.16 N 8.5i I099.95 1.13 N 9.68 i199.95 0.98 N 10.05 1299.90 1.29 N 7.00 1399.'70 0.06 S 0.91 1499.16 3.06 S 9.1i 1597.9t 7.69 S 24.16 1695.85 13.09 S 43.6,2 1793.21 16. I1S 66.24 1889.65 18.14 S 92.59 1984. :_::9 20.05 S i 23.02 2078.31 21.98 S 158.66 2169.72 24.24 S 199,,i3 -. or. S :.:44, 53 '":.' '":"5 o '7,-? :Z/.: ...... ~:.:, 4._ 30 37 S 294 63 2429.60 3:4.02 S 348.24 2513.:24 38.22 $ 402.88 2596.03 42.92 S 458.77 2678.29 47.87 S 515.4i 2759.89 53.41S 572.96 2840.59 59.18 S 631.72 2920.65 65.96 S 69i.27 3000.93 72.7I S 750.5i 3081.65 79.49 S 809. i3 3162.98 86.58 S 866~88 PAGE B O',S S .... 169 F29 ,': i 60 O,'ii: AF'RIL !7..,. i'""-"-' VER T i CAL.L,;"q-K'-'_ ,..., :::;ECT I ON L E 0.00 0 = 00 W --0, 48 (;. 29 ~ r 7 0 W .... 1 J,' ,, i2 W -2.24. 0, 33 W -:3. i ! O. 2:5 3244.3:9 9:3,,77 S 924.59 3326.04 10t.00 S 98t.:9<) 3407.99 108.28 S 1038.63 3490.38 115.97 S !094.79 3572.87 123=64 S 1150.79 W -3,, 58 0.22: W -3.89 0 ,, :i :2 W -4.85 O, 4,6 W -5.82 0.4 i W -7.04 O. I9 W -8.35 0.09 W -9.4.3 O, 13 W -9.73 O, 46 W -6.98 i = 98 W --0 ,, 8:3 i. 97 E 9,, ,SO 2.;:,, 45 E 25..'.5:1 :3.06 E 45.41 2,, 6i E 67.61 2 ,, 25:;' E '- '-' 9Fi "" 2A E i 22.05 2.43 E i56.0i 3, i6 E 194.6 i 3.00 E 2:::.':7.94 :3. i 4, E 285.98 :3.12 E 3 ::ii:7 .'2:4. '-' ,~ .:~, ~- ...,~ ,.. E 5:::::9. "-' 9' ..... :::: / 0 .... E 4.43,, 74 0.92 E 49:::. 40 0, 54 .:,.:,4 t2--': 0.7:3 E 896.91 0.06 E 952.91 O. 35 E i008.58 O. 26 E i C, 6:3 ?' F-,' 0 '=;":* E i 1 ~,,8.01 (). :[ .1 NL SPERRY-SLIN.. INC. PAGE 2 LINION OtL CO. OF CALIF. G-6, RD TOTAL D I RECT I ON ANGLE DEPTH DEG DEG MIN 4, OOA ....S 81 . ,_,':' E :B4 9. 4t00 S 81.1E 33 56, 4200 S 80.9 E 33 37 4300 S 80.4 E 33 29 4400 S 80.0 E 33 50 4500 S 80.4 E 34 24 46,00 S 80.0 E 34 12 4700 S 79.7 E 34 3 4800 S 75.1E 34 4i 4900 S 74.0 E 36 13 F;,300 S 73 '":' ":'¢: ...... ~ E -,:, 46, 5100 S 73.0 E 37 24 5200 S 71.6, E 3/_-, t9 5300 S 70.1 E 37 1 5400 S 68.0 E 36 28 5500 S 66.3 E 35 26 5600 S 6,5.0 E 33 23 5700 S 6,3.9 E 34 26 5800 S 62.0 E 36:22 5900 S 60.6, E 39 2 6000 S 59.6 E 40 47 6100 S 59.1E 41 38 6200 S 58.0 E 41 21 6300 S 57.2 E 40 47 6400 S 56.8 E 39 42 ......... ,.2 E .:,"~/ 16, 6600 S 55.0 E 36 It 6700 S 53.9 E 35 46 6800 S 53.1 E 34 56 6?00 S 52.3 E 34 17 7000 S 51.3 E 33 47 7100 S 51.0 E 33 37 7200 S 47.? E 33 3 7300 S 50.0 E 32 50 7400 S 49.4, E 32 46 7500 S 48.4 E 32 16 7600 'S 47.9 E :B2 It 7700 S 47.4 E 32 14 7800 S 46,.4 E 32 16 7900 S 48. t E 29 57 VERT I CAL LAT I TUBE DEF'AR't'LIRE DEF'TH FEET FEET 4070.86 177~33 S i481.i0 E 4153.56 i87.09 S 1536.45 E 4236.41 I97.10 S i59i.54 E 4318.6,4 211.74 S i646.54 E 4399.32 228.02 S 1703.33 E 44.79.43 245.32 S t760.62 E 4558.88 263.08 S 1818.70 E 4639.45 28i,.77 S i874.90 E 4719.29 302~27 S 1931.52 E 4799.71 324.53 S t986.62 E 488t.18 347.83 S 2039.71E 4964.67 371.09 S 2089.59 E 5047.14, 395.97 S 2i40.37 E 5127.66 423.81S 2192.73 E 5205.34 454.72 S 2247.60 E 5281.05 487.78 S 2303.94 E 5355.78 521.90 S 2360.96 E 5430.85 556.9t S 2416.98 E 5506.56 592.30 S 2471.90 E 5583.50 627.28 S 2525.35 E 5A/-,::: 08 6,6 t '-"-' ..... . . 0..:, ~; "" ~-' ' r_- ,,.,' o 7._,, 06 E 5743.79 695.70 S 2623.43 E 5824.92 730.14 S 2670~66 E 5906.89 764.53 S 2716.46 E 5989.5! 798.98 S 276,1.03 E 6,072 '"" -"""' 74 ...... .0..:, l=:.z, .z:. ~; "::' Fl (') 4. . Zf. ":~ E /. "Pi'=' 9t ,=v'-o .,-],:, S 2847 44 E 623'?. 73 903,, 7 t S 2889.1 ;'-, E 6,323.75 938.55 :-]; 2930.69 E 6407.84 973.78 S 2971.79 E 6,492.39 I009.23 S 3011.7I E 6577.0I i044.94 S 3051.24 E 6 6, 61, ?:;.. 9. 1081 , o.. .... ~ ..,':' :B 090 ,, ...~; i E 6746,14 1117,87 S 3t29. i7 E 6832, 79 I151,2i S 3166.:B3 E BO:SS- i 698".:.:',' / 16006 APRtL i7, .i. 982 VERT I CAL DOG S E F: T i 0 N L E G 1173.56 0.35 1228.15 0.45 i282.32 0.34 1336.40 0~31 t39i.07 0~,42 i44,6.45 0.60 150i,64 0,30 1556,66 0,23 16t3.25 2.6Y 1672.10 1,d,5 I '7:B i. '79 0.7:B 1792.38 O. 65 185t. 55 i. 37 19i i. 75 t, I4 19'71 t '7 I ":'":' 2029, C)9 i.47: 2083.98 2,18 2140,,3t i.22 2199~i7 2.2:2 2261.46 2.79 2325. '.-.'.'0 i. 87 239 t ,, 35 0. ? I. '-' "' =;" "::'0 0 7i~: :2520. 14- 0, 77 2582.57 i. 1:2 264 J.~ :B6 2.64 2698,, 64 i ~ 08 '-'" ~.~5. ~ z. 7 .....07 () 77 2810, 14 O. 5:'5 2864~ 09 O. 79 2917.05 O. 76, 2969.69 0,24. :'q(h '7: '[ .","', ,... ~. 3072,, 47 0,, 23 3123,,, 45 0,., 33 · .::, 173, 4-20, / 3223,, i i 0,, 28 3272.70 (),, 27 332i. 98 O. 53 3368, 6 i 2 ,, .4.6i: NL E;PERRY-'..':;LtN., I NC,, UNION OIL C:O. OF CALIF. G-6 F..'D TOTAL D i RECT i ON ANGLE DEF'TH DEG DEG MIN 8000 81 O0 8200 8300 8400 L.--; 50,,4 E 28 43 c. P;(':~. 0 E .~'-"-'.':, · _,'=' 5(::,. I E 30 47 S 51.2 E 27 38 S 51.0 E 27 57 8500 8600 8700 8800 8900 S 58.5 E 25 I9 S 59.0 E 29 32 S 57.6 E 29 19 S 56.7 E 28 58 S 56.3 E 28 20 8?50 ?000 9050 7100 9150 S 6,0.0 E 25 54 S 64.2 E 23 34 S 67.0 E 21 52 S 64.9 E I9 17 S 64.2 E 17 44 9200 9300 9400 9500 ?6,00 S 62.2 E 16 10 S 60.6 E 13 14 S 64.7 E 11 t3 S 81.6 E I3 54 S 82.7 E I4 8 9700 9800 9900 10000 10100 S 82,,6 E 12 41 S 82.4 E 1I 41 S 82.2 E 10 5 S 82.8 E ? 26 S 8:1.7 E 8 39 10200 10300 10400 10500 10600 S 7?. 0 E 7 37 S 79.6 E 7 29 S 81.5 E 7 3 · =, oZ. 6, E 7~.'-'"'"".,..:.' S 85.4 E 8 49 10700 10800 10900 11000 N 87.4 E 10 43 N 85.6 E 11 36 N 85.6 E I1 36 ,::,._,, 6 E 11 .'_..:e, VERT I CAL LA ]' I TLIDE DEPTH F'EET 6920.48 1i81.84 S 7007.66 1213.34 S 7093.56 1246. i7 S 7182.14 i275,,24 S 7270.48 1304.74 S / ._-,o<..:~ 1227 ,:-.~7 S 7447 ':":' 1 '~"='-' ,,..,,_, .:.,...,z., 46, .=,'-' -.".=;'-'Pi 07 1::-:78 70 S / ._ ..'",._ . . ., e.,.,:z.. ~/-, 1405 2":-,' S 7710.57 14, :B ! .6, 2 ._,'::' 7755.55 1442.54 S 7801.38 1451.24 S 7847.78 1458.51S 78?4.?7 1465.52 S 7942.60 1472.15 S 7990.62 1478.64 S 8087.96 1489.88 S 8186.05 1478.17 S 8283. I2 1501.70 S 8380.09 1504..8i S 8770.64 1519.44. S 9069. vq 1 ._ .. I S 9167.03 ~523.6,1 S 9268.20 1525.26, S 9367.02 1526,. 4? S 9465.27 1525.65 S 9563.23 1524. i0 S 9661.i8 1522.56 S 9757.14 1521.02 S B Kt:,; S- i 6 9 8 9 / i 6, 0 0 6 APR]:.L 17, i9E.:2 OEF'ARTURE VERTI CAL DOC-: F'EE T SE C T ]: ON L E:rS 3203. :;:,'6 E 34 i 4,: 14 i ,, 67 :B240.89 E :B46(},, 4-7 0,, 65 328<:,. 16 E 3508.8':? t. 45 3316,. 32 E 3553.05 :':,~,. 20 3352.74 E 35'P7.62 0,, 32 .::, ._4 U .~,', i 9 E: :.:: 6 :z: '.-.,', ,_,.'- ._=:i ,..'si. .27 34.31.44. E.: 36:.::::. 18 4.23 3472.79 E 3736.18 0,,72 3513.27 E 3783.50 0,,56 3552.75 E 3827,, 7';: O. ~..'..,7 3571.66 E 385t.36 5.9! 3589.6,6 E 3871.28 5.83 3606.80 E 3889.89 4.05 3621~76 E 3?06.36 5.35 3635.47 E 3921.53 3. i5 3647.78 E 3~35.36 3.33 3667.74 E :3958.01 2.96 3685.31E 3?77.40 2~2i 3709.08 E 4000.84 4.53 '-'~"-'~''~1E 4o24 ~;'"' 0 36 3755.08 E 4045.92 1.46 3775.14 E 4065.61 1.00 3792.48 E 4082.66 t~6,0 3808.76 E 4098.59 0.65 3823.64 E 4113.26, 0.81 :B908 20 E 419=' 3:4 "" ":'~ 3?28.25 E 4213~51 3948.30 E 423i.68 0.00 3968.35 E 4249.85 0.00 THE DOGLEG SEVERITY tS IN DEGREES PER ONE HLINDREB FEE]', THE VERTICAL SECTION WA::; COMF'U]'ED AI_ONG S 69' 2 E BASED UPON TANGENTIAL TYPE CALCLIt_ATIONS,, THE BO't"TOM HOLE DISPLACEMENT IS 4.24':?. 85 FEET:, iN THE DiRECT]:ON OF' S 6,? 2 E BOTTOM HOLE DiSF'LACEMEN]' IS RELATIVE TO WELLHEAD. VERTICAL SECTION !S RELATIVE TO WELL. HEAD. -50~.00 TRUE NORTH Scale: 1" = 500' --2ooo. oo Method of Calculation: Tangential HOR I ZONTRL .PROJECT I ON 0.00 Union Oil of California Our Boss Gyroscopic Survey . Job No. Boss-16989/16006 Well: G-6 RD (S~C29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey D~te: April 17, 1982 Operator: Everett Sellers Scale: 1" = 2000' Method of Calculation: Tangential 4000.00 6000.00 8000.00 10000.00~ 4249.85'. ~ S69° 2'E llOOO '" ~0~'o. oo "~o~°'oo ~obo. oo VEBT I CaL PROJECT I ON '-'t ' .~ NL SF'ERRY--.:, JN NC. F"AC..¢E ! LINION OIL CO. OF CAL!F. G-6 RD TOTAL D I REF:T I CIN ANGLE DEF'TH DEG BEG MIN 0 N O. 0 E 0 0 100 N 86.7 W 0 t7 200 N 66.0 W 0 20 300 N 66.4 W 0 40 400 N 85.3 W 0 3]. 500 S 78.0 W 0 19 600 S 83.8 W 0 12 700 N 50.9 W 0 35 800 S 88.4 W 0 36 900 S 84.7 W 0 47 1000 N 89.3 W 0 48 1100 S 88.7 W 0 40 1200 S 68.0 W 0 14 1300 N 84.3 E 1 46 1400 S 77.6 E 3 34 1500 S 73.3 E 6 0 1600 S 72~9 E 9 4 1700 S 74.5 E 11 39 1800 S 82.4 E i3 I1 1900 S 85,,6 E 15 20 2000 S 86.4 E 17 45 2100 S 86.9 E 20 55 2200 S 86,.8 E 23 55 2300 S 86.7 E 27 3 24.00 S 86.0 E 30 9 2500 S 86.1E 32 30 2600 S 85.6 E 33 14 2700 S 85.2 E 34 7 2800 S 85.0 E 34 39 2900 S 84.5 E 35 19 3000 S 84.4 E 36 1i 3100 $ 83,,5 E 36 49 3;200 S 83.5 E 36 36 ,.:,c,,. .... S,_,._,. 4 E .:,e,. 10 8400 S 83~0 E :35 35 VERT I CAL LAT ! TUDE OEPARTLtRE DEPTH FEET FEET 499.98 0.75 N 599~98 0.68 N 699.98 0.98 N 799,:98 1.28 N ':":;":;' 97 I '::'c~ N 999.96 1.!5 N 1099.95 1.15 N I199.95 1.06 N I299.92 1.13 N 1399.80 0.62 N 3.3i 3.75 4.32 5.24 6.44 7.81 9.!0 9.87 8.52 B. 95 1499.43 1.56 S 4.10 i598.58 5.38 S 16.63 1696.88 t0.39 S 33.89 1794.53 !4.6,0 S 54.93 1891.43 17.12 S 79.41 1987.27 19.09 S t07.8i 2081.60 21.02 $ i40.84 2174,,01 23. Ii S 178.89 2264.25 25.55 S 221.83 2352.02 28.61S 269~58 2437.43 32. I9 S 321'.43 2521.42 36~12 S 375.56 2604.64 40.57 S 430.82 2687.16 45. :B9 S ~,:,/. Oe 2769,,09 50.64 8 544.18 B 0 S S - 16 '.::/89 / i 6006 AF'Rt! .... 17.~ I982 V E R T l C A L B 0 G ::; E F: T I tin~ c:'Q E 0,, O0 0 :: 00 W -0, 24 0,, 25;' W - 0, 7. ::~_ 0, i .,:_":' W -i. 66 0, :B3 W -:2.68 0 ~ 25 .¢. o.z U & 02 34 . :l},'::, ,~ _. ._, 29:30, 62 6,2.57 8 661,50 3010, 79 69, '::'":' $ / ~ .) ,::, :/ 3091 29 '~/: ...... / .:,. 10,..,'::' 779 , ~:;:~: :..317. 2 , o'-'..,.: .... ,_,°._,':' ,, 04 f-:; 8 :B 8 ,01 ':"::'=-]":' A/-, 90 18 :-i; ::: 9 F, 74 :33:35, 19 97. :38 S 95:3, t 9 341 '?, , 02 1 <")_ 4. ~. 64 S I 0.. 10 .21 3499, !9 1 i2, 13 :::.; I066.71 · .:-_-:, .~.. 62 119 ~: ;-3 i S i 122. '79 W -7,, 70 O. 09 W -8.89 O. 13 W -9.58 0 ~ 46 W -8.35 i ,: 98 W -:3. ':7,0 i ~ 97 E 4 ,, 39 2 .. 45 E 17.45 3.06 E 35.36 2,, 6 i E 56,, 51 2, 29 E 80.27 2 ~ 28 E i07 48 ":' 4:::: E I ::::9.01 :B, I 6 E 1-,= 29 , , ..:,, :3 00 E :216.24 :3 ,, .I. 4 E 26:1.. 9:2 :3, ! 2 E 31i. 61 2. :35 E :36:L:: ,, 54<..D, , E 416,, 73 0, 92 E 470.99 O. 54 E 526.17 0 ,, 73 E 868, 54 O, 06 E 924, 76 0, 35 E 980, 59 O~ 26 E i 0:3,{:,, 01 0, 52 E 1091. 12 O, J. i NL SF'ERRY-.'.--:L~N, i N C. F'AGE.~.. LiN I C;.iN 0 i L F':Fi_ _ ,, OF Ur=d_-'" I F,, G-6, lq:D TOTAL D I REC:T I ON ANGLE VERT I CAL I; ,:.F r,-i DEG DEG i'i I lq DEPTH 4000 E; 81.8 E :34 9 4100 S 8!,,1 E 33 56, 4200 S 80.9 E 3:3 37 4:300 S 8(),, 4. E :33 29 4.400 S 80,,0 E 33 50 4500 S 8(),,4 E 34 24. 4600 ',:.; 8 0.0 E :3.4 12 4.700 S 79.7 E :34 3 4800 S 75. i E :34 4i 4900 S 74.0 E 36 ~3 5000 S 73.2 E 36 46, 5t00 S 73,,0 E 37 24 .'.'~'.--'F~C~ ':' 71 6 E :':!;6 19 5300 S 70,,I E 37 I 5400 S 68.0 E 36 28 6000 S 59.6 E 40 47 6!00 S 59,,1 E: 41 :38 6200 $ 58.0 E 4i 2t 6300 S 57.2 E 40 47 64.00 'S._,o='/. 8 E :39 42 6500 S 55.2 E 37 16 6600 S 55,,0 E 36 11 6700 S 53.? E 35 46 6800 $ 53.1 E 34 56 6900 S 52.3 E :3:4 17 7500 ._,':' 4- 8 ,4 E :.32I ,":,... 7/:.,00 S 47' ':) E: ":'":' 11 7700 S 4'7.4. E 32 14 /oL.(... S 4E, 4 El :35.2 i6 7?00 $ 48.1 E 29 57 :2;6,6,4..:'-'= 3747. 1 ! :38 30,24 3913.58 3':7,'i;'6.82 4079 ~ 60 4162.21 4244.99 43:27.53 4408,, 98 4489~38 4.56'P,,16 4649.16 4729.37 4809,,50 4890.45 4972.93 5055.91 5t37.4:[ 5216.5! 5293.20 5368.42 5443.32 5518.71 5595.03 5673.29 5753.44, 5834.36 59i5.91 5998.2I 6081.07 6, t64.27 6,247.82 6,33t.75 6415,,80 6500.12 6584.71 666':..9. '" .J:, i (2, .- ...~-.:) ~ ,.,., 6837,, 47 LATITUDE FEET 35, '.-.-,'7 44: 6,'.'.:, 53.64. 6,3, 07 ! 72.62 182.21 192. i0 204.42 219.88 236.67 .,;:.._,4, 2() 272.42 292. O2 313.40 336. I8 359.46 383.53 409.89 471.25 504. 84 539.4 t 574.6,1 609 ~"' . ,.'.::,44.56 ::, / ,::,, 77 712~ 92 747.33 78 !. 75 816.36 851,i6 886. i4 921.i3 956. i7 991,50 027.08 063,, 00 099 ~ 4.6 i :34..~ 54- E; S S S S S S S S B O'.E; S,,- 169:3'? / :!_ 6, 006 APR i DEF'ARTURE FREE]. V E R T i C A L [) ;..Ti G Fl; F F': T 'ir C)N 17:3 :t, 97 E i 70 :I. ,, 7 i ,:}. 7:3 1789.6,6 E ! 76, I. 85 0,, 6,5 t 846.,. 80 E i 821.73 i. :37 1903, 21 E i 88 t ,~ 41 :t ,, J..4 i i;'5'i.".'. 07 Ei 94 :[. 2:2 I ,, 38 2013,16 E !999.89 i.43 2064.65 E 2056~30 :2,,18 2114.~8 E 2111.91 i,22 :2166.55 E 2169.51 2,,22 2220.16 E 2230~08 2,,7? 2275.77 E 2293.46 I~$7 2332.45 E 2358.41 0.9! 2388.97 E 2423.57 0.78 2444,,44 E 24,87.?7 0.77 2498,62 E 2551.16 !.i2 2550.20 E 26 i i ,, 78 2:, 6,4. · -':, r:~,,,~, C', "; =''-, · ' ," = ...... . ,::.., E ~. o o ::~. :3:2: .I. ~ 0 ;3 2647.04. E 2'726.69 0.77 26,93.56, E 2782,, 45 O. i75 --, .... ,,-, 7=; . ' ..... 0 7 z./' .:, o, , ._ E'd :-'~:.::~ 6 ,, 97 · -:,c,.-:,~l 'P4 E 294, :3 24. 0 2/~ 2868.30 E 29!;:'5,, :34 O. 82 2909.93 E 3046.73 0~23 295i.24 E 30¢7. E~6 0~33 UNION OIL CO. OF CALIF. G-6 RD TOTAL ~. i RE_,T i ON ANGLE DEPTH DEG DEG MIN 800(} 8100 8200 8300 8400 S 50.4 E 28 4:3 · _(.) 0 E 2'P 20 S 50. i E 3:0 47 S 5.1..2 E 27 38 S 51,,0 E 27 57 8500 8600 8700 8800 8900 S 58.5 E 25 19 S 59.0 E 29 32 S 57.6 E 2'.;.' I'.-7.' S 56.7 E 28 58 S 56.3 E 28 20 8950 ?000 ?050 9100 9150 S 60.0 E 25 54 S 64.2 E 23 34 S 67.0 E 2i 52 S 64.9 E 19 I7 S 64.2 E 17 44 9200 9300 ?400 ?500 9600 S 62,2 E 16 10 S 60.6 E 1:3 14 S 64.7 E 11 13 S 81.6 E 13 54 S 82.7 E 14 8 9700 9800 9900 10000 10100 S 82.6 E 12 41 S 82.4 E 11 41 S 82.2 E 10 5 S 82.8 E 9 26 S 8i.7 E 8 39 10200 10300 10400 10500 10600 0700 0800 0900 1000 N 87.4 E 10 43 N 85.6 E II :.:,:6 N 85.6 E I1 36 N 85.6 E 11:36 NL :,Z.:F'ERRY-SLIN, iNC,, VERT I CAL LAT I TUDE DEF'TH FEET 6926.64 1i66.5:3 S 70 i 4.08 11 '.E/7 ,, 55."/ S 71 ,.")0 61 i .7.,-';, <, 75 c. 7187~86 1260,71 S 7276.."_--':2 i 289.99 S 7365.69 1315.91 S 7454.39 1339.77 S 754!.4.9 1365.58 S 7628.82 1391,99 S 7716.58 1418,,45 S 7761.07 !430.50 S 7806.47 1440.3t S 7852.59 t448.30 S 7899.38 t455.44 S 7946.79 1462.25 S '7994 6 t 14..:,o~ 81 8 8091.30 1480.9:3 8 8189.02 1490.70 S 8286,59 1496,61S 8383,61 1499,92 S 8480.88 1502.89 S 8578.62 1505,,64 S 8676.81 1508.!6 S 8775~36 15!0.38 S 8874~12 1512~49 S ,:, .', / o. 1 i 1 8 ..5 t 4, ,, 84 9072,, 24 1517,28 S 917i. 43 1519. ,'.5:7 S 9270.64 152i~10 S 9369.63 1522,,, 54 S '7468, 16 i ... ~=. / ..:, L:; ':}.~/-, A 0'7 . ..:,.c 1 =" ' ......... ,4 S 9664,23 1520, O0 S 9762,, I8 1518, 46 S PAr3E 3 BOSS- i 6989 / APRIL i7,_,.'982 DEF'ARTURE VERT I '-'"" nor~ F E E T ::; E C T I 0 N L E G 3 i 84.85 E :3391 ,, 35 i ,. 67 3222.13 E 34,37= 28 0= 6,5 :]:)26C,. 53 E :3484,, 66 ~ ,, 45 3298.24 E 3530,, 97 :'"::. 20 :B 3 :B 4.._.~ ._,":' E .:,'-' ._, = '"'/._, = . :B 4 C,. :32 3370.~7 E 36i8,,65 4~27 3410.32 E 3663.94 4.23 3452.:[i E 3712.21 0~72 3493.03 E :3759.87 0.56 3533.01E 3806.68 0.67 3!552.34 E 3829,, 04 5,,, 'P i 3570.79 E 3849.79 5,,83 35:5:8.36 E 3:369,., 05 4= 05. 3604.4.1 E 3886,, 59 5.35 36 i 8.74 E 3902,, 41 3,, 15 363i.76 E 391 3654.05 E 3942, 07 2.96 3672.8I E :B963.09 2.2i 3693.48 E 3984.5i 4,,53 37 ~ 7.48 E 4008.10 0,, :36 374.0.48 E 4030.63 I,, 46 3761.40 E; 4051 ,, 14 t :, ()() 3780. I 0 E 4069.51 i ,,., 6(} :B796.9.1. E 4085,, 99 0,65 38.1.2.49 E 410I,,29 0.8t 3826.44 E 4115,16 i,,!O 3839.35 E 4128,09 0. i5 3851.83 E 4t40.49 0~50 3864.26 E 4i52,=7I 0~35 3878.27 E 4166.30 I=50 3895.20 E 4182~ 18 2.26 :':':914.5i E 4199.78 0= 95 3934.56 E 4,217,, 5:"5 0 .,, 00 :3954.61 E 423,:.':.,,, ! i 0,, 00 , THE DF]ALEFG ,,::,~:'.,.EF,.ITY !.::, IN DEGREES PEF? ONE HLtNDRED FEET,, THE VERTiC:AL SECTION WAS COtdF'UTED ALOhIG S 69 0 E' BASED UPON TRAPEZOIDAL 'TYPE CALCLILATiONS,, THE BOTT'OM HOLE DZSPL. ACEMENT IS 4236,, ii FEET, IN THE DZREC'TiON OF' S 6':T.-' 0 E BOTTOM HOL. E D I'-''" ..... 'r. ........ . ............... .::,F L~..,L. EI'h~.N ~ l S RELAT.~. VE TO WF:[ I HE:'AF~ VE Iq:T i CA L S E C ]" I 0 N I S ';' "'" .... V E ,, F'.EL,...~ r ITO WEL~LHEAD -50~.00 TRUE NSRTH Scale: 1" = 500' Method of Calculation: Trapezoidal --2000.00 HORIZONTRL PROJECTION 0.00 2000.00 Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16989/16006 Well: G-6 RD (SEC29 T9N R13W) Trading Bay Unit Kenai, Alaska Survey Date: April 17, 1982 Operator: Everett Sellers Scale: 1" = 2000' Method of Calculation: Trapezoidal 4000.00 6000.00 8000.00 lO000. O0~ 4236..11' 0 S69° 0'E 11000 20~0.00 40~0.00 80~0.00 VERTICflL JECTION Suggested form to be inserted in each "Active" well folder to check for timelY compliance with our regulations. Wel ~'N~e and Number / and Materials to,be received by: ~--/Z--~ Reports R~uired Date Received Remarks Completion .......... Report Yes /~, ~us ~ p/ - .... Core ~scription .,Registered, Su~ey Plat , Inclination Su~ey ~~. Dire~i°nal ~ey Drill Stm Test Re. ms , Pr~u~ion Test Re~rts Document TransmittaJ.,~ Union Oil Company of Calif~,,.~ DATE SUBMITTED ACCOUNTING MONTH 6-14-82 I TO FROM William Van A!en R.C.Warthen T .... AT 3001 Porcupine. Box 6247 ,,, TELEPHONE NO. TRANSMITTING THE FOLLOWING: i G-6~D 1 Bluel~,,,~ ~,,~ I sepia of ~,,: fr~'loxing' DIL GR SP 5" DiL GR S? 2" BHC SP GR 5" FDC Bulk Den. 5" FDC ~"' ~ ~l~L ru~ u~i ~v 5" I I' Gamma Ray Ga...c~ R,y Cull crt Lo~ 5" ...... 1 mag. tape #63013 ....... FDC CNL C/H 5" !'~ /]'/PLEASE SIGN AND RETURN ONE (',OPY' RECEIVED' ~ ~ :" r I~: r- ,, ~," ]. 4 ~.' ' ~',t.~cR;t Dit ('. '.,~.~.'., t,..;,i.>. {. ~O~lm 1 2M02 ~REV 11-72~ P~N'rE0 ~N U '~.A .... f STATE Or:: ALASKA ALASK~ ....... '_AND GAS CONSERVATION C( MISSION ~'~,/~~~ MONTHLY REPORT OF DRILLING AND WOFIKOVER OPERATI 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 82-33 ~. Address 8. APl Number P0 BOX 6247 ANCHORAGE AK 99502 50- 733-20073-01 9. Unit or Lease Name TRADING BAY UNIT 4. Location of Well at surface Conductor 46, Leg #2, 1879'N & 1382'W of SE corner, Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. OT oo, ~Cl ~RI lRT3rl 10. Well No. TBUS G-6 RD 11. Field and Pool MoARTHUR RIVER FIELD For the Month of MAY ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Ran dual 2 7/8" X 3 1/2" completion Released rig $ 12:00 hrs 5/19/82 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where rUn None RECEIVED .16. DST data, perforating data, shows of H2S, miscellaneous data Perfed: 10175-10195' 10398-10383' 10075-10105" 10383-10368' 10030-10045' 9950- 9970' JUN - I J982 Acidized "G" zone w/ 480 bbls of acid 7. I hereby certifY t~at the foregoing is true and correct to the best of my knowledge. SIGNED TST DRLG SUPT 5/27/82 DATE NOTE rt on this orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ~ STATE OF ALASKA f ALASKA. LAND GAS CONSERVATION CI, ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONSJ · Drilling well ]i~ Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 82-33 3. Address 8. APl Number PO BOX ~;247 ANCHORAGE AK 99502 50- 733-20073-01 4. Location of Well 9. Unit or Lease Name at surface TRADING BAY UNIT Conductor 46, Leg #2, 1879'N & 1382'W of SE corner, Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RT _99 ' MSI ADL 187:~0 10. Well No. TBUS G-~; RD 11. Field and Pool MoARTHUR RIVER For the Month of APRIL ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks K0P 8 8922', footage 2078' Hit csg stub on 1st attempt to get out of window - successful on 2nd try TD ll,O00' MD 13. Casing or liner run and quantities of cement, results of pressure tests Ran 2491' 7" 29# butt liner f/ 8509-11,000' Cmt w/ 600 sxs - tested to 3000 psi - ok 14. Coring resume and brief description None 15. Logs run and depth where run DIL-Sonic f/ 11000-8917' FDC-CNL f/ 11000-2500' CBL-VDL-GR f/ 10850-7800' Gyro f/ 8922-surface 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed: 9950-9970' '10030-10045" 10075-10105' 10175-10195' Dry tested liner lap w/ tool e 8407' - ok 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ DIST DRLG SUPT 5/6/82 SIGNED ~ ~-... C~OO~_~-__~,, ~ TITLE - u. - DATE NOTE--RepOt on this form is required for e~h~lendar month, regardless of the status of operatibns, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA __ ' ,~, ALASKA AND GAS CONSERVATION C 41SSlON '~/,/ MONTHLY REPORT DRILLING AND WOAOVER OPERATIONS..?" · Drilling well [] ~~ 5 /(. 2. Name of operator UNTON 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface Conductor 46, Leg #2, 1879'N & 1382'W of SE corner, Sec. 29, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ..... ,,~, I ~n~ 1873n I'~ I ~ ' I'I..)L-- .... For the Month of. NARCH ,19 7. Permit No. 82-~ 8. APl Nu~)~_20073_01 50-- 9. Unit or Lease Name TRADING BAY UNIT 10. Well No. TBUS G-6 RD 11. Field and Pool 82 McARTHUR RIVER FIELD 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations 00:01 3/23/82. Milled window 8917-8977' 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run Gyro survey 9600' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Sqz'd 10630-11354' Perfed & sqz'd 9001-9003' 8921-8923' RECEIVED MAY 1 o 1982 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED~*',--..- ~. t~t~,~ /QS~ T,TLE D~ST DRLG SUPT DATE 4/15/82 NOTE--Re~ort on this form is reqUiredf°~each~calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 (~ STATE OF ALASKA ALASKA -AND GAS CONSERVATION CO ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ~ COMPLETED WELL [] OTHER F'] 2. Name of Operator 7. Permit No. ' UNION OIL COHPANY OF CALIFORNIA _ 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well Cond. 46, Leg 2, 1879'N & 1385'W of SE corner, Section 29, T9N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) -- RT 99' MSL 12. 6. Lease Designation and Serial No. ADL 187~0 8. APl Number 50- 733-20273 9. Unit or Lease Name TRADING BAY UNIT 10. Well Number TBUS G-6 RD 11. Field and Pool HcArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] - Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The KOP has been changed from 7100' MD to 8922' the same. Verbal from Oim~Tr~mble 3/26/82. The Hemlock zones were abandoned~-- as follows: MD. The bottom location remains Moved rig #54 over conductor #46, leg #2, TBUS G-,6 and rigged up. Killed well, installed BPV, removed tree, installed and tested BOPE to 3000 psi. Pulled and laid down existing completion equipment. Set retainer at 9695' and squeezed w/ 350 sxs cl "G". RECEIVED APR 1 2 1.982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~,,,~ (~-~. C~L~L~_ ~,~. ~ Title DIST DRLG SUPT The space b~(~w ,-or Commis-sion use ~- Date 4/6/82 Conditions of Approval, if any: Approved by ORIG!T~L SIGNED BY LONNIE, C. Sl~illi ~pproveo . y Return ~cl By Order of CQMMISSlONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~areh 19, 1982 Ur. Robert T, ~qderson District Land Manager tInton Oil Company of CaIifornia P. O. Box 6247 Anchorage, Alaska 9950g Re~ Tradin~ Bay Unit TBUS G-6 RD Union Oil Company of California Permit No. 82-.33 Sur. Lo~. 1879'1i, 1383'It~ of Sli er ~ee ~9, TS~, R13W, Bott~ole Loc: !3~0~, ~2690'~ of S~ c~ Sec 28, TS~, ~13~, ~. Dear ~ir. Anderson: gnelosed is the approved application for per, it to drill the above referenced well, t~ell samples and a ~ud lot~ are not required. A continuous directional survey is required as per 20 AAC 2.$.050(b)(5). If available, a tape containing the dtl~itt, sed log iflfo~atton shall ~ submitted on all lo~$ for copyi~ ex~ept e~erimental logs, velocity surveys and dt~eter surveys. ~any rtve~s in Alaska and their d~atna~e systems have been eiasst.fied as' important for the spa~in~ or mt~ratton of anad~o~us fish, Operations tn these areas are subject to AS 16.05..~70 and the ~egulations pr~l~ated thereunder (Title 5, Alaska Administrative Code). P~ior to c~ncin~ operations you my be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Artiole ? an~ the rei~ulations p~omul~llated thereunde~ (-Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water Pollution Control ACt. as amended. Prior to eommenein~ operations you may be contacted by a representative of the Department of Environmental Conse'rvation. Mr. Robert T. An~ae rson Trading Bay Unit TBUS (t~6 ~ -2- ~lareh 19, 1982 To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would at so like to be notified so that a representative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandone~nt, please give this office adequate advance notification so that we ~ay have a witness present. Very truly your-s, C. V. ~at Chai~an of BY ORDER OF TH; COMMISSION AlaSka Oil and Oas Conservation ~ission ~.c I osure De:pal, tment of Fish ~ Game, Habitat Section v//o enel. Department of J~nviron~ntal Conservation w/o enel, ~C~be ALASKA OIL AND GAS CONSERVATION COMMISSION ,lAY I HAMMOND, GOVERNOR March 18, 1982 3001 PORCUPINE DRIVE-ANCHORAGE. ALASKA 99501 ADMINISTRATIVE APPROVAL NO. 80.40 Re.: Application of Union Oil Company of California, operator of the Trading Bay Unit, to redrill, complete and produce the T__rading Bay Unit G-6RD well as part of the pressure mainten- ance project--by Conservation Order No. 80. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on March 16, 1982 and stated that the drilling, completion and production of the Trading Bay Unit G-6RD well will provide a crestal final with- drawal point in the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry W. Kug , Commi s s i one r BY THE ORDER OF THE CO~0i~/IISSION Union Oil and Gas~'=vison: Western Region Union Oil Compan¢of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager Harch 11, 1982 Hr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001Rorcupine Drive Anchorage, Alaska 99504 WEST FORELAND AREA State of Alaska HcArthur River Field Grayling Platform, TBUS G-6 Rd. ADL-18730 (8-86-71-5575-601352) Dear Hr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Rermit to Drill TBUS G-6 Rd. for the Grayling Platform. Also enclosed is our Check No. 19186 in the amount of $100'00 to cover filing fees. sk Enclosures (4) Very truly yours, cc: O. R. Callender A. Lannin-LA Office MAR 1 2 1982 Alaska 0il & Gas Cons. C0rnmiss~D Anchorage g STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. ' DRILL [] lb. Typeofwell EXPLORATORY E] SERVICE [] STRATIGRAPHIC [] REDRILL,~ DEVELOPMENT OIL ]~ SlNGLEZONE [] DEEPEN [] DEVELOPMENT GAS E} MULTIPLE ZONE,~ 2. Name of operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at. surface 9. Unit or lease name Cond. 4:6, Leg 2, 1879'N & 1383'W of SE cot S.29 TDN R13W SM TRADING BAY UNIT At top of proposed producing interval 10. Well number +646'N & +2345'E of SW corner, S.28 T9N R13W SM. TBUS G-6 RD . At total depth 11. Field and pool +320'N & +2690'E of SW corner, S.28 T9N R13W SM. - - I 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RI 99' MSL ADL 18730 McARTHUR RIVER FIELD 12. Bond information (see ~0 AAC 25.025) National Fire Insurance Company of Type Statewide Surety and/or number HartfOrd (B5534278) Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed Southwest 57 1/2 miles 2690' feet well 1200' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 12000' MD feet 3840 ~4~/15/82 19. If deviated (see 207110AAC 25.050) o 120. Anticipated pressures +__~UUU+__~00 psig@C)~I'7 Surface KICK OFF POINT feet. MAXIMUM HOLE ANGLE22I (see 20 AAC 25.035 (c) (2) psig@ --~---.ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 8 1/2 7" 29# N-80 Butt 4000' 7000' I --- +1099~ +9730 +1100 sxs inside ' i ' ~ 5/8" csg. I I I I ' I I I ~ I 22. Describe proposed program: See attached R CEIV£o MAR 1 21982 AiasIca Oil & Gas Cons, ComlTIj$$iOi. Anchorage 23. I her y knowledge SIGNEI;~" HoDert. I, Ancerson / TITLE District Land Mgr DATE 3/11/82 The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log requi~:ed Directional Survey required I APl number []YES ~NO I-lYES [~NO ryES []NO ' Permit number .~ reval date .... ~/~r~ .,,~' //~/~/~2 "[ SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY , ,COMMISSIONER DATE -// ~ v/,. by order of the Commission ..... Form 10-401 ~., Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL TBUS G-6 RD 22. Proposed Program: . . . . e e e 10. 11. 12. Move Rig #54 over conductor #46, leg #2, TBUS G-6 & rig up. Kill well, install BPV, remove tree, install and test BOPE. Pull and lay down existing completion equipment. Set retainer abover permanent packer and squeeze cmt into Hemlock perfs for abandonment. Run CBL & squeeze 9 5/8" casing for stabilization. Mill window in 9 5/8" casing from 7100' to 7170' +MD. Spot KO plug across window and dress off to +711~. Mix mud. Directional drill 8 1/2" hole from 7110' KOP to +10996' TMD. Run DIL, BHC-Sonic, CNL-FDC-GR from KOP (+7110' MD) to TD. Run 7" liner, CBL, Multishot gyro, and squeeze. Complete well as dictated by logs. Install BPV, remove BOPE, install and test tree. Place well on production. tVtAR 1 2 982 Alaska Oil& Gas Cons. " CATE VALVE · e- ;RE'CEIVEi) MAR 1 2 1982 Alaska 0il & Gas Cons, Commis Anchorag~ · · · - - · IH&?~ULI£ OPEP~ T£D · VALVE ·. '.' . · / · ZO-TOR~UE · o · · · o _uo~ ' ALL CHANGES J~1UST HAVE V/RIT..TEN AF, PRCVAL BY THE DISTRICT DRILLII'~G SUPERINTENDENT · -. ~' ..: :'.~ · . .p.. --:-;... ~;; ~ ' · i ' ' '' ' -': ':"' ' ' :'~"~ · .. · . , . '.'o. . : :.-.. - · ... · k,,, .~:,~,~ ,~ '' '-.,, ~- " '" '. -" ~'~r~-~,-~,~..- .- -'-' · . . ' MAR 1 2 19,~32 .. Alaska Oil & .. .o UN,~ON OIL COMPANY OF CALIFOr, NIAr' .:, .... ~ CASING AND TUBIN0 DESIGN c~s~ ~ ~.,~ .... ~,.~-, a,',~, co~ C~ZNG SI~ 7 HO~ SIZE ,,psi/ft., M.S.P. I~T~VAL LEA%~TH DESCRIPTION '~IGHT TENSION }-~ NI.M~4 TDF COLLAPSE C0LL~PSE ~/B~ _ -top of '$T~OT'~ P~SS. @ aESIS~. Bottom Top Wt. Grade Thread W/O B~zf section TENSION bottom tension lbs lbs 1000 lbs psi psi BU~T YIELD psi psi_ PRiG PER Fi'.. Y=Tensile L. oad/Pipe Yield Strength oo , ..~ .!.'-, .6 .8 _l.o ~ ~!:il:-.:.,.::...,:-..,: !,: :~ li.."~'!,..,,. ! ~i?i I:. ~ ~ .... ' ; ; ~-'~'~ '-:'--' ' "--T' "' ml"': ..... :-'." :.'1";"~ .... · ~::~;I;::';*:':.:'."~ . .':.'~:7:1.~:~'o. ~.,.,. . .... ,.,..: ...... ":: i;.". '::u':.:' :;':;i;':: "°:'.:;'~'1'..I'~'~;:~ ~.., ...... I ........ I..:..,~..i:'~m~:..',~'..'.,'..~ e~ '' .................... i.,/~...,, ..... ,-.,, '. I" ', ........ I": ..... : ;' :'" ~;~ ~" ~:" ,...:.-. ..... ~, ....... ,~1.';'~.1 .............. "-"-- ~' - 1 '~..:.'1...'~..~---'--""". !~':.t;"::.'-;::l'::" ",;i; Y::' .h.' %~."', ...:_:__. ~ ............ L.u...,.,.J .1 . ~ ...... .at .... :~.1 ...... ~.:.;..'!~' .~i,'"..qql.~..: .... ......... , ....... ~, :, · -..1.~-., -' · ..I ~ ..~,..., .. . · ,~ ,.,L: ,.~ , ,.,'~1 - ... Formulae: ~ Collapse resistance in tension = X (Collapse pressure ratify) Burst Pressure = }rap +. Depth ( Hyd. Gr. II --.~) BF (Bouyancy Factor) = ~.oo- (o.o~ x ~u~ w~. ~) ', '. '.. :,',.'.;t-..." Calculations: Totm. i Co~t ..~.__t..~_:_,., .J4...~.,.i_..,_..l.. Ir-,, ,':) ' ;t ~:'"~'~,, ...... ., ........ ~, :,.! .... -.,.-,!--, .............. . j !, ,,.,--! i-;.~. ~-~.-~ .... -, ...... ~, .... , ............! Ih f lNG ,-PLATFORM .......... ~ ....... J ............ ! I ......... ,...~ ............ , .. .... ..... ,.- 1, ' ' [ i---~-~--' · ] ' I SCA ' I - 0 t- -t"~' '"~ ........ ~ .... ;'~ ..... ~",'-'*, -'; ..... ~ "** ........ '*':'~ .... ~-' [ t"i'- ...... ""',I-~-'t-'~-~, ~-- f-*~, ...... 1. ;'d ....... b'.'[!, ~ B:Y, :i';'-'' ~ ,;'" t-t . ,~-~'"'~'~ "';. ~'; ..... .il" ................... , :., ! :,~' ...... ~ :. ~ ....... , ~i ;' ~ ..... , L- _.,~_-""~'""~' ...... , ' :"'T' .''''~-~ ~ ,?'' ..... ~ 1'-"-"--': ........... : ' ~ '"~' ----' ..... "~, : .................. ~ ·, ~' ....... 1 r : , '~ ,~ , -' ...... " .... ,'---r- ........... : I ': : '" ~', , :, :, .... ~ ....... ! I ' ..~ ~, _i~ , _:. '-'-~ ~ i' ...... ~-""; ..........; ¢ ...... II : ' ,. r , , ~ ~ ........ : ., ; ~ ....... ...; ....................: ' ~-,--!--i--,-.~--t. l-i- .i--t ~ -- II- - ,LAND.DIRECTIONAl.;. DRILLING :, ,;. , i.: ' ~ . ' · ~--r-, . . [ t~-'-t ........ i-'~"~"I1 .... '~ ............ It ......,_,..~ ,.~t ..... ~---t ..... ~ ....... 0 ............... :'~-.J000' ' ' ~ 8000 ........... ' : $OOO ....... ' '~'~,OO0' ....... .: ......... · ~4 ..... ' · [ ' ; , I-. , ' : : , ; i i , '. t : ' . ' . ' ". "-, · ' ' : ' : '" , , , : '~ ...... .... ~i'-! ......... T~ I' -~t-~' .t ."'i' i ,,TVD 'it . ~ . : · ' · .-m-F-eooo-+ f -~ 4,.--k~--:.-. ~-, 'i:)E:P =-0'~'-' ';'""-~ol-:-:-'"4---;-"i---:--:---~ '" ........ ~.,-.-I ...... '-- ", :- I -,.--~ · ;'-; '~, -'~ --!-"~'t~Zo?-"-"i'-f-:-4-1-4'-''~-'- i,--:,-.-J- 1000 ~' '~ .... ' ......... ~ ........... ' .... t ' . : I I t ' ? ' ' ! ' ~ " ' ~ [ ~' -- ' · ~ · " ' ' I [ "' -[ ...... ~ , . , ]*, ....... '., :, H! ,........J ; ! i~,~'.. .... ,-,--,- -.h!- ..!.~~. o ' : , ' , , 11/2 PER ~ ~- - * - ~ t ' : ........ L-'.'-~ ' '.i ~.-.!,. ' i .... ~ ~ ~ -:-, , ., TVD. 6885. , , .... ~'~'","~ I l'l'i', ............i .......... ~ t .......... ~ ....~ -':": ! ........ i""~'-? ........ · ..... ..... :"*:':- -' .... ,' .... ~MD-~'929~' '~' ": t .......~" .... '":.- ; --', --~ ",'- ', , '~ .-:-'... '.. ;'~ -~ t ' '' "~., ":'~'~'~..-~ .... **"T .... :'-~*". ! ,F-,- .~-;-*-. f'1 :~~ ......... · . ~ ': ......... ~ , ~ 'AVERAGE' A GLE ~1' Ol9, ~' ,:'~-'"], .......I ~', ~ . . ..... . , , ,:""~ ~ ~ ...., L_,,, ;*"~""~'-~., ...... I'-+""~ ....... , , ,~ ..... .......... , -- ~ ............ · tI j , ,, . ' , '..: 't, ........ , : . . ' ........ , : , ; , ', . : . . .: -~, j~ .... ~ ~ , ;' t ~ ', ' , ' '~! * { '"-~, .~ ..... , ~t' .... I ,~' ~), .... ~ ..... ][ : .... ?. ': ....... [ ~. .... r , ...... ] ! ........... ! ; " ......... "-"-""?'1 "' i ...... r'"~".-?" ..i ~ .... ;i: i";'"~!': i~":.~' '~'°0o': '"" ;'~"~ '-' "· "' .... :'", ~ :"' ...... - ........... [ ;': ...... 'TTM ....... ~ ...... ~-'"~'-' ...... ..... .... ~"'" ........~ '.', ~ '~ ..... ~ 't ..... ~ ....:' , '~ .' '~':' '-~ :', 'i" ,'~'~': t.' .... ,'-~ .................... t I .... t ..... ~-',-,.",-': ..... ? .... . . , , · ............... ..... ~ ........................... : · .' ....................., ~ , , , -~' '~ ,'-' ~.~--I ........ ~ ~-. . . ; · ~ ' . ' ~ ~ i ~ : , : ~ , , ~ , , ~ . , . , ~ ' . , -. ~ . ~.-~ . --~. ~ , l, , · ~.., [ ~ ~ARGET B . . .. ' . , . , . , : ' ', ' '. , ...., , 1. . , . . ~ ' I t . ' I ' ' -: .... ' ; ~ '~ ,:.:~ ~:'1.,,,.~: , ~ .... ~.. ~,~l ~.:~l~.~:,~...,.~.l__,~,.~ .~ .... ~ .... ;.lr.t_.~...., ~..:.,l~...:...~..,...!,.__~--:l ..... ~-'-'"-?' .... ll .... : ~ '"i i' .' : ...... ..... ~..:..~, .~ ....... ~' ~" .... ~ ............... ~ ...... ~l-IO 000 .: ...... ~.l~_. ...... , ~.l~_;.~ .............. ~ ....... : ...... ~ ~.: ..... ? ! ..... ~ ...... ~ ............, ..... ,-~ ~--t ............... ~ .... :. ._ .... :_T.~_.~ .... ,. .......... ~ l_~.,... .............. I-'~ "~ '; ...... ~_;1 l. .... . .1 , ....... ~ r .... t" .:.l.~ ..... . . .:..[ ~ ..... t"~ ....... ~. ~ .... .... ,,i ~ ' ,~:.l' ....... : ..... ....... ? [ - :',"~'] '- ~ .... . ' I ~ ' .... .-~ ---; q ...... ~ .:*4 .t ':~_ '~-,--~ ..... 7', .... : .......... :-'~ ' ' "'.,":. T. ,."'. .......... ~ , '~ .... 'r · ' ' ........ 0 , ' [. . . ,. r ~, ~ .' ~. [ ~ I, ~ , . , .... , , · ' . . , ....... . . t , ' ........ , t'~ ....... , ~ ~ ' .... 1 ............... · ............... ~--,'-','-~ .... ?-, ....... , ...... ~' ' ~' --, ...... '-, ....... ", .-, ...... ~- .-~., ....... ,--I--,4 ...... j:~f ~-~-~ ''~''' .... ......................... ' ...... ~ .... r--'~' ' ' ' ~ ~ t ~ I' ~ ~ ' . . ' ' ~ 4z;_~:;.h:~.L~.' .; ~.i.l.: ..... ,.,. ........, ...... .._,t tt.Z 4.0 ~ R i~ ,. S ,,. O It K- I~ RD TO 14,01~ ?C' tl~94 . . ~. TO 12.447 %. i ~ ~ ~ tO 14,700 ' (-17 ~'~ '~ '" '- '~ ~" K~ RD~ · TD N ?* ,~. ~-~2~ ~ ~% -. ,,; · ~ .... ~. . _ .~., . _ '--- ~"~ ...... 10,240' TM D ~~. ~.,O~Z; ~ '~--~-~-~'~ "~ ,, 9,617' TVD 'o,~sso , ~. GF ~L~, - ~ L;~ ~~ ~:; ~ '. re'-,., .... ." ~ ,~oo. r~, ,~ ,, _ ~ , F~ .. , · ~.~0 .,~ ~ ~.~ ~/ ,~;,¢~,t''.o'o ~, ~,,.,,og~. . '~ U-~U ~ ,, . . ~. ~' ": ....... ' ' ' ,, _ ,/ ' ;~ e D-7 ~G-~ ~" ' " '-~mJ7 ~.:~ ~'~ · ./ ~~_~~ '~~ ...... . .... / ./,,,~,o~/~:~j.~ ~s .,~ ~,,.~L~; . - -~ u~~ ........ · D'20 ~31 , ~ ,, ~o,z z~ ,, , / /',"~T/~~~D-3/ ' ,,/e~ '~ ~ ~ '~ PROPOSED '~ J~/~~~.;C~ ,~¢~~ · ~ ~ ~ ~ WELL LOCATION ~ {~ ~ ~~ ~~/ ~~' , ~ '. , · . ~. ~ ~ ..~' ~ , - . , CHECK LIST EOR NEW WELL PERMITS Company Lease & Well No. IT~ APPROVE DATE (1) Fe.e . ~ fO ~ 2. Is well to be located in a defined pool ........ 3. Is well located proper distance from propertY 1 i ii 4. Is well located proper d±stance from other wells ......... 5. Is sufficient ~undedicated acreage available in this pool ........... 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... (3) Admin ~"f~' ~'1~'~/ 9. (9 thru 11) 10. 11. (12 thru 20) 13. 14. 15. 16. 17. 18. 19. 20. (4) ,Casg (21 thru 24) 22. 23. 24. YES NO REMARKS (6) Ada: 2.5. Does operator have a bond in force ....... Is conductor string provided ....................................... 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 surface casing protect fresh water zones ...................... 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 well bore separation proposed .......................... Is a diverter system required ............. ~ ......................... _~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to 3ooO , psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. 7P Additional requirements ' .~_ leeeeeeleeleeeeee~ee'eee~eeeee®eeeeeeeee®eeeee Additional Remarks: Geology: Engi.~e ~r ~ng: ,.cs d2 WVA J KT ~ RAD rev: 01/13/82 INITIAL GEO. UNIT oN/OFF POOL cLAss STATUS AREA NO. SHORE · , Well Histo.ry 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 APPENDIXl No Special'effort has been made to chronologically organize this category of information. ,o ~mmmmmmmmmmmmmmmmmmm~ ~ .... SCHSUMBERG£R .... · LIS TAPE VERIFICATION LISTING LVP OiO.HOI VERIFICATION LISTING PAGE *~ REEL HEADER ** SERVICE NA~E :SERVIC DATE :82/04/16 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER ~* SERVICE NAME :SERVIC DATE :82/04/16 ORIGI~ :1070 TAPE NAME :61013 CONTINUATION ~ :0! PREVIOUS TAPE : COM~EN~S ~TAPE CO~ENTS ** FILE HEADER FILE NA~E :$ERVIC.O01 SERVICE NA~E : VERSION # DATE : MAXIMjM LENGTH : 1024 FILE TYPE : PREVIOUS FILE ** INFORMATION RECORDS MNE~ CONTE~TS CN WN : FN RANG: TOWN: SECT: COUN: STAT: CTRY: UNION OIL COMPANY OF CALIFORNI TBU G-6 RD (24X-28) MCARTHUR RIVER 29 29 KENAI ALASKA USA MNE~ CONTENTS PRES: NEDIT4F RECORD TYPE 047 ~ UNIT TYPE CATE SIZE CODE 000 000 030 065 000 000 020 065 000 000 014 065 000 000 00] 065 000 000 002 065 000 000 002 065 000 000 006 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP OiO.HO1 VERIFICATION LISTING PAGE 2 RECORD TYPE 047 ~ RECORD TYPE 047 ~ COMMENTS ~ PACIFIC COAST COMPUTING CENTER } - ======~ ~= ------------------'----''~----------======================~-- COMPANY = UNION OiL COMPANY OF CALIFORNIA WELL = TBU G - 6 RD (24X-28) FIELD = MCARTHUR RIVER CObNTY = KENAI STATE = ALASKA JOB # 1.0707,630~3 DIL RON ~1, LOGGED ~4-APR-$2 BOTTO~ LOC ., INTERVAL 0954 FT. TOP LO(; INTERVAL =8901 FT. CASING-LOGGER = 9.66 IN. ~ 8901 FT. BIT SIZE : 8.5 IN. TYPE ~OLE FLUID = DUDVIS GEL DENSITY : 9.3 VISCOSITY : 6~.0 PH : 9.5 LVP 0i~3.~Ol VERIFICATION LISTING PAGE 3 FLUID LOSS RM ~ M~AS. TEMP. RMF 9 MEA$. TEMP. RMC ~ MEAS, TEMP, RM ~ BHT 7,8 C3 0,363 Ia 68 F 0,232 ~ 57 F ~.103 ~ 57 F 0,376 9 165 F MATRIX SANDSTONE ~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 8 4 73 60 9 4 65 .lin 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API APl API FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS ~OD NO. LEVEL CODE DEPT FT 0 0 0 0 0 4 0 1 68 SFLU DIL OH~ 7 0 0 0 0 4 0 i 68 ILM DIL OHMM 7 0 0 0 0 4 0 ! 68 ILD [)IL OHM~ 7 i2 46 0 0 4 0 ! 68 SP DIL MV 7 1 0 0 0 4 0 ! 68 GR DiL GAPI 7 31 32 0 0 4 0 ! 68 NPHI FDN PU 42 68 2 0 0 4 0 ~ 68 RHOB FDN G/C3 42 35 I 0 0 4 0 1 68 DRHO FDN G/C3 42 44 0 0 0 4 0 1 68 CALI ~'DN IN 42 28 3 0 0 4 0 ! 68 GR FDN GAPI 42 3~ 32 0 0 4 0 ! 68 NRAT FDN 42 42 1 0 0 4 0 ! 68 NCNL FDN 42 34 92 0 0 4 0 ! 68 FCNL FDN 42 34 93 0 0 4 0 I 68 DT BHC US/F 60 52 32 0 0 4 0 ! 68 SP DHC MY 60 ! 0 0 0 4 0 1 68 GR BHC GAPI 60 31 32 0 0 4 0 ! 68 NPHI CAS PU 0 68 2 0 0 4 0 ! 68 RHOB CAS G/C3 0 35 1 0 0 4 0 1 ~8 DRHO CAS G/C3 0 ~ 0 0 0 4 0 ! 68 CALI CAS IN 0 28 3 0 0 4 0 ! 68 GR CAS GAPI 0 31 32 0 0 4 0 ! 68 NRAT CAS 0 42 ! 0 0 4 0 ! 68 LVP OiO,HO1 VERIFICATION LISTING PAGE 4 NCNb CAS FCNL CAS DATA DEPT SP DRHO NCNb GR CALl FCNL 99 -99 12 -99 -99 DEPT SP DRHO NCNL CALI FCNL 090 . 329 7 -99 -99 DEPT SP DRHO NCNL GR CALl FCNL lOGO -2 ]45 5 -99 -99 DEPT SP NCNb GR CALI FCNL 10700 -15 0 4188 61 -999 -999 DEPT SP DRHO NCNb CALl 10600 -61 -0 3636 57 -999 -999 DEPT SP DRHO NCNb GR CALI FCNL 10500 -59 0 3904 -999 -999 0 34 92 0 0 0 34 93 0 0 0000 i0313 250O ,2500 9375 : soo ,2500 ,0000 ,5313 .0359 ,5000 ,9375 ,2500 ,2500 .0000 ,0858 .0000 .~I09 , 500 .250O ,0000 .5313 ,0244 ,0000 1250 : soo ,2500 ,0000 ,0313 ,0029 ,0000 ,4141. ,2500 ,2500 ,0000 ,7813 ,0542 ,0000 ,4375 .2500 ,2500 SFLU FCNG NPHI GR SFLU GR FCNL NPHI GR SFLU GR CAbI FCNL NPHI GR SFbO GR CALl NPHI GR SFLU GR CALl FCNL NPHI GR SFLU GR CALl FCNL NBHI GR 7.3047 121,9375 NPMI -999.2500 GR -999,2500 DT -999.2500 RHO8 -999,2500 NRAT 5.0820 73.9375 NPHI 8.7227 GR 1170.2500 DT -999.2500 RHO8 -999.2500 NRAT 12.5781 IbM 50.2109 NPHI 9,9922 GR 1622.0000 DT -999.2500 RHOB -999.2500 NRAT 17,2656 ILM 61.t250 NPHI 8,6719 GR 71 0000 DT 27,0469 57.4141 NPHI 8,3281 GR 1362,0000 DT -999,2500 RHOB -999,2500 NRAT 29,5625 IbM 51.4375 NPHI 8.5859 GR 2286,0000 DT -999,2500 RHOB -999.2500 NRAT 4 0 4 0 7.3633 -999.2500 RHOB -999,2500 NRAT 77 5625 SP -999:2500 DRHO -999,2500 NCNb 5 4922 ILL 26:2623 RHOB 78,5000 NRAT 81,8750 SP -999,2500 DRHO -999.2500 NCNb 15,6797 ILL 5 062 HRAT 67,3906 SP -999.2500 DRHO -999.2500 NCNb 21,4219 ILL 24,8535 RHOB 68,3438 NRAT 73.8750 SP :999,2500 DRHO 999.2500 NCN'L 19,203i ILD 24'3652 RHOB 52,1562 NRAT 72,4688 SP -999,2500 DRHO -999,2500 NCNb 17.7031 13,4277 RHOB 41,0313 NRAT 68,9687 SP -999,2500 DRHO -999,2500 NCNb I 68 i 68 7.8008 -999.2500 -999,2500 -13,0313 -999,2500 -999.2500 5 7695 2 4711 2 6416 -0 5313 -999 2500 -999 2500 15 2969 2 5060 2 0502 -25 2813 -999 2500 -999 2500 4727 2 4121 -!5 5313 -999i2500 -999 2500 21.0469 2.4414 2.3516 -61.03t3 2999,2500 999,2500 i 6406 1 5391 1 6436 -59 7813 -999,2500 -999,2500 LVP 010.H0! VERIFICATION DEPT 10400,0000 SFLU MP -85.8125 GR DRHO 0.0096 CADI NCNb 5190.0000 FCNG GR ' 44.8516 NPHI CALl -999.2500 GR FCNb -999,2500 DEPT 10300.0000 SFbU SP -14.5313 GR DRHD 0.0t76 CALl NCNb 3162.0000 FCNL GR 66 8672 NPHI CAbI -999:2500 GR FCNL -999.2500 DEPT 10200.0000 SFLU SP -83,3125 GR DEMO -0.0005 CALl NCNb 4888.0000 FCNL GR 49 1250 NPHI CALl -999!2500 GR FCNb -999 2500 o oo.oooo o DEPT I0000.0000 SFbU SP -61.0313 GR DRHO 0 0171 CALl NCNL 2874i0000 FCNb GR 84 2344 NPHI CALl -999.2500 GR FCNL -999,2500 DEFT 990~ 5625 GR SP -7 ~0000 SFLU DR~O ~ 0195 CALI NCNL 397:0000 FCNL GR 62.3750 NPHI CALI ~999,2500 GR FCNb 999.2500 DEPT 9800,0000 SFLU SP -49,53t3 GR DR~D 0.0059 CAhI NCNb 4424.0000 FCNb GR 63,4063 NPHI CALI -999.2500 GR BISTING 357.2500 IbM 44.8516 NPHI 8.5284 GR 4017,0000 DT -999.2500 RHOB -999.2500 NRAT 14.2266 66.8672 NPHI 8.8437 GR 14t2.0000 DT -999.2500 RHOB -999.2500 NEAT 44.7813 IBM 49.1250 NPMI 8.4453 GR 2904.0000 DT -999.2500 RHOB -999,2500 NEAT 39.0000 IbM 46.3750 NPHI 8.3438 GR 2156.0000 DT -999.2500 RHOB -999,2500 NEAT 14.i328 84.2344 NPMI 10.3594 GR 05.5000 DT 13.984~ IbM 62.3750 NPHI 8.3281 GR 1536.0000 DT -999.2500 RHOB -999.2500 NEAT 22.8437 ILM 63.4063 NPHI 8.2813 GR 237~.0000 DT -999.2500 RHOB -999.2500 NEAT 66.1250 7,9052 RHOB 43'9141 NEAT 57.3828 SP -999.2500 DRHO -999.2500 NCNb 10.2500 22.4121 RHO8 61.1719 NEAT 85.2031 -999,2500 DRHO -999.2500 NCNb 43.1562 4.1113 RM~B 5,0938 NEAT 56.5859 BP -999,2500 DRHO -999.2500 NCNb 36.2813 19 ~8'24 RHOB 44:125 NEAT 74,0156 SP -999.2500 DRHO -999.2500 NCNb 8,7969 27"7344 RHOB 9616875 NRAT 79.9844 SP -999.2500 DRHO -999.2500 NCNb 11.8906 IbD 24.6582 RHOB 64.4004 NEAT 78.7344 SP -999.2500 DEMO -999.2500 NCNb 20.9844 IhD 16.2598 RHOB 50.3438 NEAT 85.8750 SP -999.2500 DRHO -999.2500 NCML PAGE 104.8125 2.5837 . li2695 85 8125 -999 2500 -999 2500 i0 8984 2'3926 212617 -14 5313 -999 2500 -999:2500 40 0938 2 5684 1 6768 -83 3125 -999 2500 -999,2500 44 0938 2 4023 2 0273 -141 3750 -999 0 -999 ~50 50O 9 9141 2 4980 2 7422 -61 0313 -999 2500 -999 2500 14 2031 2i4297 2 3711 -79 5625 -999 2500 -999:2500 9219 3~ 3242 1 8076 -49 5313 -999 2500 -999.2500 LVP O]().M01 VERIFICATION LISTING PAGE 6 FCNL -999.2500 DEPT 9700.0000 SFhU SP -47.2813 GR DRHO 0 0239 CALI NcNL 3088:0000 FCNL GR 100 0625 NPHI CALI -999!2500 GR FCNL -999 2500 DEPT 9600.0000 SFLU SP -87.3i25 GR DRHO 0.0249 CALf NCNL 3~52.0000 FCN5 GR 62.2734 ~ NPHI CAbI -999.2500 GR FCNL -999.2500 DEPT 9500.0000 SFLU SP -65.3125 GR DRBO 0.0088 CALl NCNb 3848.0000 FCNL GR 60.1172 NPHI CALl -999,2500 GR FCNL -999.2500 DEPT 9400.0000 SFLU SP -60.5313 GR DRHO 0.0103 CALI NCNb 2672.0000 FCNL GR 53.7109 NPHI CALI -999.2500 GR FCNL -999.2500 DEPT 9300.0000 SFbU SP -40.0313 GR DRHO -0.0425 CALI NCNb 2428.0000 FCNL 5625 NPHI DEPT 9200.0000 SFLU SP -46.2813 GR DRHO -0.0039 CALI NCNL 4216,0000 FCNL GR 60 7266 NPHI CALI -999~2500 GR FCNL -999,2500 DEPT '~100 0000 SFLU DRHO 0.0016 CALI NCNb 1527.7500 FCNL 18.i406 IbM 100.0625 NPHI 10.35!6 GR 8I 0000 DT 6.4297 IL~ 62.2734 NPHI 8.5938 GR 144i.0000 DT -999.2500 RHOB -999.2500 NRAT 10.4609 IbM 60.i172 NPMI 8.4063 GR 1712.0000 DT -999.2500 RHOB -999.2500 NRAT 53 109 NPHI 8.4844 GR 1096.0000 DT -999.2500 RHOB -999.2500 NRAT 76.3750 IbM 75.5625 NPHI 9.2578 GR 544.0000 DT -999.2500 RHOB -999.2500 NRAT 7.3047 IbM 60.7266 NPHI 9.3438 GR 76 0000 DT -999.2500 NRI~ 168.3750 IL~ 47.85!6 NPHI 14.5703 GR 306.5625 DT 9.9375 26.1719 106.9375 75.6250 -999,2500 -999.2~00 5.2109 27.0996 55.8125 84.8750 -999.2500 -999.2500 10.4766 21.3379 46.4375 81 3750 -999~2500 -999.2500 11.2500 24 95~2 86.5313 -999.2500 -999.2500 13.3516 60.A398 76.3438 101.8281 -999 ~500 -9992 500 7.4727 21.1426 49.4375 85.0781 -999.2500 -999.2500 37.0000 65. 6372 37 3750 ! 8:125o RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNL RHOB NRAT SP DRHO RHOB NRAT SP DRHO NCNb RHOB NRAT SP NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT i0 5313 2 5703 2 6387 -47 2813 -999 2500 -999 2500 .i641 ~.3945 2 5547 '87i3125 -999 2500 -999 2500 ii 4844 2 3926 2 1543 -65 3125 -999 2500 -999 2500 13.3594 '2 3457 2 4004 -60 5313 -999 2500 -999 2500 19 2344 ~ 7451 4 5234 -40 0313 -999 2500 -999 2500 8 2734 2 3652 -4~ 2187 2813 -999 2500 -999 2500 7750 5.0093 -60'0313 GR CAbI FCNL DEPT SP DRHO NCNb GR FCNL DEPT SP DRH~ NCNb CAbI FCNL DEPT SP DRHO NCNb GR CAbI FCNL DEPT SP DRHO NCNb GR CAbI FCNL OiO.HO! VERIFICATION 47.85!6 NPMI -999,2500 GR -999.2500 9~00,0000 SFUU 87.3125 GR 0,0664 CAbI 3528.0000 FCNb 49.3359 NPHI :999 2500 GR 8900.0000 SFbU -26,!406 GR -~ 1201 CAbI 2iI :oooo CNL 39.7656 NPHI 8.7656 GR 652,5000 8800 0000 SFbU -999i2500 GR -999 2500 CALI -999~2500 FCNL -999:2500 NPHI 938 GR 8700.0000 SFLU -999 2500 GR -999:2500 CALI -999.2500 FCNb -999.2500 NPHI 8.5859 GR 404,0000 DEPT 8600,0000 SFLU SP -999.2500 GR DRHO -999 2500 CAbI NCNL -999:2500 FCNL GR -999.2500 NPHI CAbI 8.6016 GR FCNL 608.5000 DEPT SP DRHO NCNb GR CALl FCNL DEPT SP ~500.0000 SFbU -999 2500 GR -99~i2500 CAbI -99 2500 FCNL 8400.0000 -999.2500 -999.2500 RHOB -999.2500 NRAT 5.9023 IbM 49,3359 NPHI 8.6250 GR 1501.0000 DT -999.2500 RHOB -999.2500 NRAT 0.5415 IbM 39 7656 NPHI 8:7500 GR 675.0000 DT 30.9082 RHOB 42.1562 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 45.5078 RHOB 55.8750 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 41.9434 RHOB 52.0313 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 31.8359 RHOB 28.4531 NRAT -999,2500 IbM -999.2500 NPHi -999.2500 GR -999.2500 DT 35.8398 RHOB 25.67!9 NRAT -999,2500 Ib~ -999.2500 NPHI '999.2500 -999.2500 4.4258 22.0215 46.1626 16.0469 -999,2500 -999.2500 2000.0000 32.0801 38,9687 -10.8037 2.3047 3,0977 -999.2500 : 9. soo 99,2500 -999.2500 1.8369 3.8984 -999.2500 -999.2500 -999.2500 -999.2500 2.1191 3.7051 -999.2500 -999,2500 -999,2500 -999.2500 2,5293 3.1484 -999.2500 -999.2500 -999.2500 -999.2500 2.0293 3.3672 -999.2500 -999.2500 DRHO NCNb RHOB NRAT SP DRHO RHOB NRAT SP DRMO NCNb ILD RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb IbD RHOB NRAT SP DRHO NCNL ILD RHOB NRAT SP DRHO NCNb RHOB PAGE -999.2500 -999,2500 4 1328 2 3906 2 2168 -87 3125 -999 250O -999 2500 4.3359 2.5176 2.9004 -26 1406 016157 22~4 0000 999.2500 999.2500 ~999.2500 0000 -999.2500 -999.2500 -999,2500 -999,2500 -0!5186 1616 0000 -999 2500 -999i2500 -999 2500 -999 2500 2084.0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 5884 1536 0000 -999 2500 -999~2500 LVP OiO.HO1 VERIFICATION LISTING PAGE 8 DRHO NCNb GR CAbI FCNL DEPT SP DRHO NCNb CALl FCNL DEPT SP DRHO NCNb GR CAbI FCNL DEPT SP DRHO NCNb GR CALI FCNL DEPT SP DRHO NCNb GR CAhI FCNL DEPT SP DRHO NCNb GR CALI FCNb DEPT SP DRHO NCNb GR CALl FCNL -999.2500 CALI -999.2500 FCNL -999.2500 NPHI 8.5859 GR 484.2500 8300.0000 SFLU -999,2500 GR -999.2500 CALf -999.2500 FCNL -999.2500 NPHI 8.6172 GR 1053.0000 8200.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 FCNb -999.2500 NPHI 8,6641 GR 446.5000 8100 0000 SFLU -999~2500 GR -999.2500 CALf -999,2500 FCNL -999.2500 NPHI 8.6328 GR 244.1250 8000.0000 SFLU -999.2500 GR -999.2500 CALl -999,2500 FCNL -999.2500 NPHI 8,6016 GR 339.7500 900.0000 SFLU !999.2500 GR -999.2500 CALI -q99.2500 FCNL -999.2500 NPHI 8.6016 GR 281.5000 !800,0000 SFLU 999.2500 GR -999 2500 CAbI -999i2500 FCN5 -999 2500 NPHI 8.5938 GR 429.5000 -999.2500 GR -999.2500 DT 40.1367 RHOB 52.7500 NRAT -999.2500 -999.2500 NPHI -999.2500 GR -999.2500 DT 17.3828 RHOB 24.1875 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 30,6152 RHOB 27.3438 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 69.9707 RHOB 26.92!9 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 45.3125 RHOB 46.7i88 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 66.6504 RHOB 38.7188 NRAT -999.25O0 IL~ -999.2500 NPHI -999.2500 GR -999.2500 DT 38.7207 RMOB 49,3438 NRAT -999.2500 -999,2500 2.3262 3.6035 -999.2500 -999.2500 -999.2500 -999.2500 2.3359 2.3066 -999.2500 -999.2500 -999.2500 -999.2500 1.9951 3.0820 -999.2500 -999.2500 -999.2500 -999.2500 1.3750 5.2422 -999.2500 -999.2500 -999.2500 -999.2500 2.0195 3.8887 -999.2500 -999.2500 -999.2500 -999.2500 586 -999 2500 -9 :2 oo -999.2500 -999.2500 2.080~ 3.5273 NRAT SP DRHD NCNb ILl) RHOB NRAT SP DRHO NCNb RHOB NRA~ SP DRHO NCNb ILl) RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb ILD RHOB NRAT SP DRHO NCNb -999 2500 -0 5259 1784~0000 -999.2500 -999.2500 -999.2500 5410 2556.0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 6021 1538 0000 -999,2500 -999~2500 -999.2500 8989 1359.0000 -999,2500 -999,2500 -999.2500 -999,2500 -0.6133 1422.0000 -999.2500 -999.2500 -999.2500 -999,2500 -0,6338 1509.0000 -999 2500 -999:2500 -999.2500 -999.2500 -0 5835 1570:0000 DEPT SP DRHO NCNL GR CALI DEPT SP DRHO NCNb CALl FCNL DEPT SP DRHO NCNb GR CALl FCNL DEPT SP DRHO NCNb CALl FCNL DEPT SP DRHO NCNb CALI FCNL DEPT SP DRHO NCNb GR CALl FCNL DEPT SP NCNb GR CALl OiO.HOI VERIFICATION vvoo.oooo -999 500 CALZ -999.2500 FCNL -999.2500 NPHI 8.6250 GR 631,0000 7600.0000 SFbU -9992500 GR -999:2500 CALf -999,2500 FCNb -999.2500 NPHI 8,6250 GR 243.7500 75000000 -99922500 -9992500 -9992500 -9992500 86484 4125000 SFLU GR CALI FCND NPHI GR !4000000 SFbU 999~2500 GR -999,2500 CALl -999,2500 FCNL -999.2500 NPHI 8.6328 GR 352.2500 7300.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 FCNb -999.2500 NPHI 34~:~406000 GR ~ 0000 SFLU 999.2500 CALI -999,2500 FCNb -999,2500 NPHI 8.6797 GR 629,0000 lloo.oooo SFbU 999.2500 GR -999.2500 CAbI -999.2500 FCNL -999.2509 NPHI 8.6328 GR LISTING -999.2500 IbM -999.2500 NPHI -9992500 GR -999:2500 DT 31.3477 RHOB 32,3125 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 63.0859 RHOB 43,5938 NRAT -999.2500 IbM -999.2500 NPHI -999 500 GR 41.3574 RHOB 29.7500 NRAT -999.2500 -999.2500 NPHI -999.2500 -999.2500 DT 45.8984 RHOB 49.3125 NRAT -999.2500 -999.2500 NPHI -999.2500 GR -999,2500 DT 46.3379 RHOB 49.8750 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 27,9785 RHOB 29,1562 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 21.8750 RMOB 27,7969 NRAT -999.2500 -999.2500 -999.2500 -999.2500 2.1562 3.1211 -999.2500 -999,2500 -999,2500 -999,2500 1.8369 4.8633 -999.2500 -999,2500 -999,2500 -999,2500 1.9414 3.6719 -999.2500 -999,2500 -999.2500 -999,2500 t,8389 3,9219 -999,2500 -999,2500 -999,2500 -999,2500 1.9492 3.9453 -999.2500 -999.2500 -99~,2500 -99 ,2500 2.1230 2.9375 -999.2500 -999 500 -999.2500 2.2129 2.6035 IbP RHOB NRAT BP DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT BP DRHO NCNb RHOB NRAT BP DRHO NCNb IbP RHOB NRAT SP DRHO NCNb IbP RMOB NRAT BP DRHD NCNb RMOB NRAT SP DRHO NCNb PAGE -999.2500 -999 2500 -999:2500 -999,2500 -O.§776 2102.0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 5771 1295 0000 -9992500 -9992500 -9992500 -9992500 -06377 14680000 -9992500 . -999.2500 -999,2500 -999.2500 -0,6455 1401.0000 -9992500 -999i2500 -9992500 -999,2500 -0,5474 1502.0000 -9992500 -9992500 -9992500 -9992500 -05835 1927.0000 -9992500 -9992500 -9992500 -9992500 -04912 19740000 LVP OIO.HO1 VERIFICATION LISTING PAGE FCNL DEPT SP DRHO NCNL CALi FCNL DEPT SP DRHO NCNL CALI FCNL DEPT SP DRHO NCNb GR CALI FCNL DEPT SP DRHO NCNb GR FCNL DEPT SP DRHO NCNb GR CAbI FCNL DEPT SP DRHO NCNb GR CAbI FCNb DEPT SP DRHO NCNb ~03.5000 7000 0000 SF[,U '999~2500 GR -999.2500 CALl '999 2500 FCNb -999~2500 NPHI 8,6953 GR 321.5000 90O 0000 SFLU 8.6563 GR 311.0000 6800.0000 SFLU -999.2500 GR -999.2500 CALI -999.2500 FCNL -999.2500 NPHI 8.6B75 GR 247.0000 6700.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 FCNL -999.2500 NPHI 8.6641 GR 320.5000 6600.0000 SFLU -999.2500 GR -999 2500 CALl -99912500 FCNL -999.2500 NPHI 8.6797 GR 347.2500 6500.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 FCNL -999.2500 NPHI 8.6484 GR 230.7500 6400.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 FCNL -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 52.5879 RHOB 48.3750 NRAT -999.2500 -999.2500 NPHI -999.2500 GR -999.2500 DT 51.6113 RHOB 38.2187 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 62.8906 RHOB 3~.2500 NRAT -999.2500 Ib~ -999.2500 NPMI -999.2500 GR -999.2500 DT 49.5605 RHOB 48.5938 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 48.0469 RHOB 59.9062 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 69.1406 RHOB 27.4844 NRAT -999.2500 IbM -999.2500 NPNI -999.25O0 GR -999.2500 DT -999.2500 99.2500 1.7559 4.2852 NCNb -999.2500 -999.2500 RHOB -999.2500 NRAT -999.2500 1.8809 4.2344 NCNb -999.2500 -999.2500 RHOB -999.2500 NRAT -999.2500 ~.3838 DRHO 4.8516 NCNb -999.2500 -999.2500 -999.2500 NRAT -999.2500 SP 1.631~ DRHO 4.1211 NCNb -999.2500 ILD -999.2500 RHOB -999.2500 NRAT -999 2500 1:7813 DRHO 4.0391 NCNb -999.2500 IbD -999 500 NRAT -999.2500 BP 1.1074 DRBO 5.1953 NCNb -999.2500 -999.2500 RHOB -999.2500 NRAT -999.2500 SP v -999.2500 ~999.2500 .999.2500 9~9.2500 0.6553 ~342.0000 -999.2500 -999.2500 -999.2500 -999'2500 -0.5913 1419.0000 -999.2500 -999.2500 -999.2500 -9~9.2500 0.7617 1235.0000 -999.2500 -999.2500 -999.2500 - g: soo 1436.~TMooo -999 2500 -999 2500 '999i2500 -0 5996 15~i 0000 -999 2500 -999 2500 -999~2500 -1,2832 1265.0000 -999 2500 -99912500 -999 2500 -999 2500 LVP OIO.HOi VERIFICATION GR -999,2500 NPHI CALl 8.7344 GR FCN5 556.5000 DEPT 6300.0000 SFLU SP -999,2500 GR DRHO -999,2500 CALI NCNb -999'2500 FCNL GR -999.2500 NPH~ CALI 8.7422 GR FCNL 253,7500 DEPT 1200,0000 SFLU SP 999,2500 GR DRHO 999'2500 CALI NCNb 999.2500 FCNL GR -999,2500 NPHi CALI 12'17!9 GR FCNL 735,5000 DEPT 6100,0000 SFLU SP i999.2500 G~ DRHO 999.2500 CAL~ N ~ . C~L 999.2500 FCNL GR 999.2500 NPHf CALl 8.7422 GR FCNL 640.0000 DEPI 6000.0000 SFLU SP -999.2500 GR DRMO -999,2500 CALl NCNb -999.2500 FCNL GR -999.2500 NPHI CALl 8.7344 GR FCNL 573,0000 DEPT 5900.0000 SFLU SP -999.2500 GR DRHO -999,2500 CAGi NCNb -999.2500 FCND GR -999.2500 NPHI CALl 8.7656 GR FCNL 306.0000 DEPT ~$00.0000 SFbU GR SP :999.2500 DRHO .999.2500 CALX NCNb 999,2500 FCND GR -999,2500 NP~! FCNL 419.2500 DEPT 5700.0000 SFLU SP -999.2500 GR LISTING 29.3945 RHUB 41.8750 NRAT -999.2500 -999.2500 NPHI -999.2500 GR -999.2500 DT 62.6953 RHOB 55.6563 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 25.4395 RHOB 3~.828~ NRAT =999.2500 -999.2500 NPHI =999.2500 GR -999.2500 DT 30.~758 RHOB 3~.4063 NRAT -999.2500 IL~ -999.2500 NPHI -999.2500 GR -999.2500 DT 33.4473 RHOB 32,53~,3 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 53.8086 RHOB 55.i875 NRAT 2~99 2500 IbM 99~2500 NPHI -999.2500 GR -999.2500 DT 36.0352 RHOB 32.2500 NRAT -999.2500 IbM -999.2500 NPHI 1,9404 3.0137 -999.2500 -999.2500 -999.2500 -999,2500 1.5732 4.8398 -999.2500 -999.2500 -999.2500 -999,2500 2,289! 2.7988 -999.2500 -999,2500 -999,2500 -999,2500 2.1289 3.0586 -999,2500 -999 2500 -999,2500 2.1426 3.2383 -999.2500 -999 2500 -999~2500 -999.2500 1.3145 4.3555 -999,2500 -999,2500 -999,~500 -999.2500 1.3037 3.3809 -999,2500 -999.2500 DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb IbD RHOB NRAT SP DRHG NCNb RHOB NRAT DRHO NCNb ILD RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB PAGE 0000 -999,2500 -999.2500 :999.2500 999.2500 6313 2 :oooo -999 2500 -999 2500 -999 2500 -999 2500 -0 4624 2090 0000 -999.2500 -999 250o -999 2500 -999 2500 -0 5i95 I952 0000 -999~2500 -999 2500 -999 2500 -999 2500 -0 5293 1854 0000 -999,2500 -999.2500 -999.2500 -9~9,2500 !.0,8477 1301.0000 -999 2500 -999!2500 -999 2500 -999 2500 0000 -999 2500 -999.'2500 11 bVP 010.H01 VERIFICATION bISTING PAGE 12 DRHO NCNb 99 GR 99 CALI FCNL 31 DEPT 5~0 BP 9 DRHO 299 NCNb -99 GR -99 CALI FCNb 22 DEPT 550 BP -99 DRHO 99 GR -99 CALi FCNL 36 9,2500 CAbI 9,2500 FCNb 9.2500 NPHI 8,7031 GR 0,0000 DEPT 540 SP -99 DRHO -99 NCNb -99 GR -99 CAbI FCNL 69 0 0000 SFbU 9i2500 GR 9 2500 CAbi 9 2500 FCNb 9:2500 NPHI 8.6875 GR 7.8750 0.0000 SFLU 9,2500 GR 9 2500 CAbI 9:2500 FCNb 9.2500 8.6641 GR 8.2500 0.0000 SFbU 9.2500 GR 9.2500 CALI 9 2500 FCNb 9~2500 NPHI 8.6328 GR 5.0O0O DEPT 5300 SP :999 DRHO 999 NCNb -999 GR -999 CALI 8 FCNb 1082 .0000 SFbU .2500 GR ,2500 CALI ,2500 FCNb 2500 NPHI :7422 GR .0000 DEPT 5200.0000 SFLU 8P -999.2500 GR DRHO -999.2500 CAbI NCNb -999.2500 FCNb GR -999,2500 NPHI CALI ~8,7656 GR FCNL 701,0000 DEPT 5100 Sp -999 DRHO -999 NCNb -999 GR -999 CAb~ 8 FCNL 1438 0000 SFbU 2500 GR 2500 CabI 2500 FCNL 2500 NPHi 7344 GR 0000 -999.2500 GR -999.2500 DT 52.2461 RHOB 5~.2813 NRAT -999.2500 IbM -999.2500 NPHI -999,2500 GR -999.25O0 DT 71.4844 RH00 29.5313 NRAT -999.2500 ibm -999.2500 NPMI -999,2500 GR -999.2500 DT 43.0176 RHOB 46.6563 NRAT -999.2500 IbM -999.2500 NPMI -999.2500 GR -999.2500 DT 25,i465 RHOB 49.4375 NRAT -999.2500 IbM -999,2500 NPHI -999,2500 GR -999,2500 DY 16.8945 RHOB 65.9375 NRAT -999.2500 IbM -999.2500 NPMI -999.2500 GR -999.2500 DT 25,4883 RHOB 30.8437 NRAT -999.2500 IbM -999.2500 NPNI -999.2500 GR -999.2500 DT 12,1582 RHOB 33,4688 NRAT -999.2500 -999.2500 1.4834 4.2695 -999.2500 -999,2500 -999.2500 -999.2500 1.3379 5.3242 -999.2500 -999,2500' -999,2500 -999.2500 1.7949 ~.7617 -999.2500 -999 2500 -999~2500 -999.2500 2.0742 2.7832 -999.2500 -999,2500 -999,2500 -999,2500 1.6885 2,2754 -999.2500 -999.2500 -999,2500 8911 2.8008 -999.2500 -999.2500 -999.2500 -999.2500 1.5830 1'9268 NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb !Lb RMOB NRAT 8P DRNO NCNb IbD RHOB NRAT SP DRHO NCNb RHOB NRAT SP NCNb RHOB NRAT BP DRHO NCNb RHOB NRAT DRHO NCNb -999 2500 -999 2500 -0 7295 I341 0000 -999,2500 -999.2~00 -999,2500 -999,2500 -0,7959 I328.0000 -999,2500 -999,2500 -999'2500 -999.2500 -0,6758 t520,0000 -999 2500 -999!-2500 -999 2500 -999,2500 -0.5801 2039.0000 -999 2500 '999 2500 -999 2500 -999 2500 -0 6758 2596 0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 9590 2084 0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 6421 2952 0000 bVP OIO.HO1 VERIFICATION ooo.oooo FCNb 717 000 DEPT 4900 0000 SFLU SP -999i2500 GR DRHO -999 2500 CALI NCNb -999 2500 FCNb GR -999~2500 NPMI CALl 8.6953 GR FCNL 515.0000 DEPT 4800.0000 SFbU SP 99~ 2500 G~ DRanO 19 :250o CAbI -999.2500 CNL -999.2500 NP I CAbI @ 6953 GR *s:sooo DEPT 470~ 0000 SFbO SP '99=~2500 GR DRHO -999,2500 CAbI NCNb -99~:2500 FCNL GR -99 2500 NPHI CAbI '~.7714 GR FCNL 3644.0000 DEP¥ 4600 0000 SFLU SP -999!2500 GR DRHO -999 2500 CALl NCNb -999 2500 FCNb GR -999.2500 NPHI CALI 8.8047 GR FCNb 412.7500 DEPT SP DRHO NCNb GR FCNb 4500 0000 -999 2500 -999 ~500 -999 500 -999.2500 8.7656 308.2500 SFLU GR CAbI FCNb NPHI DEPT SP NCNb CAbI 4400.0000 -999.2500 -999 2500 -999 2500 -999 2500 8.7813 SFbU GR CAhI FCNL NPHI LISTING -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.25O0 DT 28.1738 RHOB 3].5000 NRAT -999.2500 IbM -999.2500 NPMI -999.2500 GR -999.2500 DT 29.2480 RHO8 32.9375 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 34.3750 RHOB 45.5313 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 3.2715 RMOB ~5.1562 NRAT -999.2500 -999.2500 NPHI -999.2500 GR -999.2500 DT 43.994i RHOB 54.6563 NRAT -999.2500 IbM -999.2500 NP~I -999.2500 GR -999.2500 DT 53.1250 RHOB 40.0000 NRAT -999.2500 IL~ -999.2500 NPHI -999.2500 GR -999.2500 DT 17.4316 RH05 42.7500 NRAT -999.2500 -999.2500 -999.2500 -999.2500 1.0596 2.9492 -999.2500 -999.2500 -999.2500 -999.2500 1.8945 3.0078 -999.2500 -999.2500 -999.2500 -999.2500 ~.8486 3.2871 -999.2500 999~2500 7871 1.1270 9 .2500 -999.2500 -999'2500 .9053 .8164 -999.2500 -999.2500 -999.2500 -999.2500 2.0293 4.3164 -999.2500 -999.2500 -999.2500 -999.2500 1.8721 2.3i05 RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT $P DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb ILD RHOB NRAT SP DRHO NCNb RHOB NRAT 8P ORHO NCNb PAGE -999.2500 -999 2500 -999 2500 -999 2500 -0 6499 2336 0000 -999 2500 -999!2500 -999 2500 -999.2500 -0.~587 1633. 000 -999 2500 -999 2500 -999 2500 -999 2500 -0 7207 ~696 0000 -999 2500 -999i2500 -999 2500 -999,2500 .0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 5532 1668 0000 -999.2500 -999 2500 -999 2500 -999 2500 -0 7051 1419 0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 6069 2252 0000 13 bVP 010,HO1 VERIFICATION 5ISTiNG PAGE 14 FCN5 9O DEPT SP DRHO NCNb GR CALl FCNL 30 - 99 99 DEPT SP DRHO NCNb GR CABI FCNb 7,5000 DEPT SP DRHO NCNb GR CAbI 0 0000 SFLU 9:2500 GR ' 9,2500 CAbI 9,2500 FCNL 9,2500 NPHI 8,7656 GR 8,5000 DEPT SP DRHg NCNb GR CAbI FCN5 4200,0000 SFbU -999,2500 GR -999,2500 CAbI -999,2500 FCNB -999,2500 NPHI 8,8359 GR 220,1250 DEPT BP DRHO NCNb GR CALl FCN5 100,0000 SFbU ~999,2500 GR -999 2500 CAbI -999i2500 FCNb -999 2500 NPH! 3088203 GR : ooo DEPT SP DRHO NCNb GR CALI FCNL ~ooo oooo SFbO 999~2500 GR -999,2500 CAbI :999,2500 FCNL 999,2500 NPHI 8'7891 GR 516,5000 DEPT SP DRRO NCNb ~900,0000 SFbU 999,2500 GR -999 2500 CAbI -999i2500 FCNL -999 2500 NPHI 8,8984 GR 569,5000 soo oooo 2 oo 8.8281 GR 255,6250 3700 -999 -999 -999 ,0000 SFBU ,2500 GR ,2500 CAbI ,2500 FCND 999 25O0 IbM -999.2500 GR -999.2500 DT 57,7148 RHOB 47.1250 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999,2500 DT 72,1191 RHOB 14.6406 NRAT -999,2500 IbM -999,2500 NPHI -999.2500 GR -999,2500 DT 51.8066 RHOB 25.2969 NRAT -999,2500 IbM -999.2500 NPHI -999,2500 GR -999,2500 DT 33.3496 RHOB 28.3281 NRAT -999,2500 IbM -999.2500 NPHI -999,2500 GR -999.2500 DT 31.5918 RHOB 28.4375 NRAT -999,2500 IL~ -999,2500 NPHI -999.2500 GR -999.2500 DT 67,4316 RHOB 27.60Q4 NRAT -999.2500 IbM -999.2500 NPHI -999,2500 GR -999.2500 DT 99 2500 -999.2500 -999.2500 1.6621 4,5703 -999,2500 -999.2500 -999.2500 -999.2500 1,3438 5,3594 RHOB NRAT SP DRHO NCNb -999 -999 -999 -999 -0 1342 RHOB NRAT SP DRHO NCNb 2500 250O 2500 2500 6431 0000 -999 2500 - g : 5oo -999 2500 -999!2500 -0 7329 i, 190 0000 -999,2500 ILD -999 -999.2500 RHOB -999 -999,2500 NRAT -999 -999,2500 SP -999 1,9736 DRHO -0 4,2461 NCNb t415 -999,2500 ILD -999 -999,2500 RHOB -999 -999,.2500 NRAT -999 -999,2500 SP -999 2,0156 DRH~ -0 3,2324 NCNb 1665 -999,2500 IbD -999 -999,2500 RHOB -999 -999,2500 NRAT -999 -999,2500 SP -999 2,0859 DRHO -0 3,1348 NCNb I874 -999,2500 -999,2500 RHOB -999,2500 NRAT -999.2500 SP 1,7471 DRHO 5,1016 NCNb -999,2500 -999,2500 RHOB -999 2500 NRAT -999~2500 SP 2500 2500 2500 2500 5713 0000 25OO 2500 250O 250O 5942 0000 2500 2500 250O 25OO 4780 0000 -999 2500 -999 2500 '999 2500 -999 2500 -0 5615 1303 0000 -999 ,2500 -999, 500 -999,2500 V LVP GR CAhi FCNL DEPT SP DRHO NCNb GR CAbI FCN5 DEPT SP DRHO NCNb GR CAbI FCNL DEPT SP DRHO NCNb CAbI FCNL DEPT SP DRHO NCNb CALI FCN5 DEPT SP DRHO NCNb GR CALl FCNL DEPT SP DRHO NCNb GR CAbI FCNL DEPT SP OIO,HO1 VERIFICATION -999.2500 NPHI 8 8828 GR 548:5000 3600,0000 SFLU -999,2500 GR :999,2500 CALZ .999,2500 FCNb 999,2500 NPHI 8'8594 GR 55o:oooo 3500,0000 SFLU -999'2500 GR -999,2500 CALf -999.2500 FCNL -999,2500 NPHI 8,8984 GR 563,0000 3400,0000 SFbU ~999.2500 GR ~999,2500 CALf 999'2500 FCNb -999.2500 NPHI 8.8906 GR 327:0000 3300.0000 SFbU -999 500 CALZ -999 2500 FCNL -999 2500 NPHI 8,9375 GR 283,7500 3200 0000 SFLU 2500 GR .-999 999 2500 CALl 8828 GR 277 2500 3100.0000 SFLU -999 2500 GR -999!2500 CALl -999 2500 FCNb -999,2500 NPHI 8.8359 GR 269,0000 3000.0000 SFGU -999.2500 GR hIS'lING 27.2461 RHOB 24.53!3 NRAT -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 31,0059 RHOB 32,2187 NRAT -999,2500 IbM -999,2500 NPHI -999.2500 GR -999,2500 DT 32.9590 RHOB 45,3750 NRAT -999,2500 IbM -999,25n0 NPHI -999,2500 GR -999.2500 DT 51,1719 RHOB 41,2500 NRAT -999,2500 IbM -999.2500 NPHI -999,2500 GR -999,2500 DT 50,0977 RHOB 39..0625 NRAT -999,2500 Ih~ -999,2500 NPHI -999,2500 GR -999.2500 DT 57,6660 RHOB 34,8125 NRAT -999.25OO IbM -999,2500 NPHI -999,2500 GR -999,2500 ST 54.1992 RHOB 45,1875 N~AT -999,2500 IbM -999,2500 NPHI 2,0996 2.8984 -999,2500 -999.2500 : 99, oo 99.2500 1,9824 3.1035 -999.2500 -999,2500 -999,2500 -999,2500 1,9844 3.2109 -999,2500 -999,2500 -999,2500 -999,2500 1,9687 4,2070 -999,2500 '999:~500 '999 5O0 '999.2500 1,9287 4,1484 -999,2500 -999,2500 -999,2500 -999,2500 1,9238 4,5664 -999,2500 -999 2500 -999i2500 -999 2500 1,8945 4.3750 -999,2500 -999.2500 DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT $P DRHO NCNL RHOB NRAT SP DRHO NCNb ILD RHOB NRAT $P DRHO NCNL RHOB NRAT SP DRHO NCNb RHOB PAGE -0 7163 1719:0000 -999 2500 50O -999 ~5 0 -999 0 -999 2500 -0 4917 1782 0000 -999,2500 -999,2500 -999,2500 2 oo 1846,0000 -999,2500 -999,2500 -999,2500 -9 :2 oo 0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 5396 1269 0000 -999,2500 -999;2500 -999,2500 -999,2500 -0 5488 1327~0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 5122 1278.0000 -999 2500 -999225oo 15 LVP 010.HO1 VERIFICATION 5ISTING PAGE 16 DRHO -999,2500 CALf NCNb -999.2500 FCNL GR -999.2500 NPHI CALI 8.8750 GR FCNL 245.7500 -999.2500 GR -999.2500 DT 6'7.1387 RHOB 19.8125 NRAT DEPT 2900.0000 SFLU SP -999 2500 GR DRHO -999~2500 CALl NCNb -999.2500 FCNL GR -999.2500 NPHI CALl 8.9531 GR FCN5 351.2500 -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 40,4297 RHOB 26.4688 NRAT DEPT 2800.0000 SFLU SP -999 2500GR DRHO -99912500 CALl NCNb -999 2500 FCNL GR -999 2500 NPHI CALl 8.8359 GR FCN5 287,5000 -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 58,7402 RHOB 26.6406 NRAT DEPT 2700.0000 SFLU SP -999.2500 GR DRHO -999,2500 CALf NCNb -999,2500 FCNL GR -999.2500 NPHI CALl 8 8672 GR FCN5 236~0000 -999.2500 IbM -999.2500 NPHI -999.2500 GR -999.2500 DT 67.8711 RHOB 21.9844 NRAT ** FILE TRAILER FILE NAME :SER¥IC.O01 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME ********** E(]F ********** ** TAPE TRAILER ** SERVICE NAME :SERVIC ' DATE :82/04/16 ORIGIN :1070 TAPE NAME :63013 CONTINUATION # :01 NEXT T~PE NAME : COMMENTS :TAPE COMMENTS ** RE~L TRAILER -999.2500 -999.2500 2.1035 5.0859 -999.2500 -999.2500 -999.2500 -999.2500 2,4863 3,6191 -999,2500 -999.2500 -999,2500 -999,2500 2.1328 4.6250 -999.2500 -999.2500 -999.2500 -999.2500 2.2i48 5.1250 NRAT SP DRHO NCNL RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb RHOB NRAT SP DRHO NCNb -999 2500 7588 1237,0000 -999 2500 '99912500 -999 2500 -9~9 2500 '.0.5215 1514.0000 -999 2500 -999 2500 -999 2500 -999 2500 -0 9512 1353 0000 -999 2500 -999,2500 -999 2500 -999 2500 -0 5259 1272 0000 bVP OIO.HOI VERIFICATION LISTING PAG~ 17 SERVICE NAME :MERVIC DATE :82/04/16 ORIGIN : REEL NAME :REEL ID CONTINUATION # :0! NEXT REEL NAME : COMMENTS :RE~L COMMENTS EOF **********
