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DIO 010
Disposal Injection Order 10 Granite Point Field 1. April 6, 1995 Unocal's application for Underground Injection 2. April 13, 1995 Notice of public hearing and affidavit of publication 3. May 21, 2004 Unocal's letter re: Confirmation of Class II Status of Fluids from Gathering Line at Granite Point Platform 4. September 14, 2004 Public hearing sign -in sheet 5. September 24, 2004 AOGCC's letter re: Confirmation 6. September 27, 2004 Proposals to amend underground injection orders to incorporate consistent language addressing the mechanical integrity of wells 7.-------------------- Monthly Pressure Reports — GP 44-11 8.-------------------- Monthly Pressure Reports — MUC 1-02 9.-------------------- Monthly Pressure Reports — GP 31-14RD2 Disposal Injection Order 10 Granite Point Field Granite Point 44-11 Well ORDERS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF UNION OIL ) Disposal Injection Order No. 10 COMPANY OF CALIFORNIA (UNOCAL) to dispose of Class II fluids by underground injection in the Granite Point Well 44-11. Granite Point Field Granite Point 44-11 Well June 16, 1995 IT APPEARING THAT: UNOCAL by correspondence dated April 6, 1995 made application to the Alaska Oil and Gas Conservation Commission (AOGCC) for authorization to inject Class II waste fluids into the Granite Point No 44-11 well. 2. .Notice of an opportunity for public hearing was published in the Anchorage Daily News on April 13, 1995. No protest or request for public hearing was received. FINDINGS: UNOCAL is the operator of the Granite Point Field. 2. Two wells, Granite Point No. 31-14 RD2 and Granite Point MUCI-2, penetrate the proposed injection zone within cone-quarter mile radius of the Granite Point No 44-11 well (GP 44-11). 3. Granite Point No. 31-14 RD 2 has 13-3/8" casing set at 2106' (subsea) cemented with 1100 sacks of cement and 9-5/8" casing set at 4344' (subsea) cemented with 675 sacks of cement. 4. Granite Point MUCI-2 has 13-3/8" casing set at 3788' (subsea) cemented with 642 sacks of cement and 9-5/8" casing set at 8297' (subsea) cemented with 600 sacks of cement. 5. UNOCAL proposes to monitor the 9-5/8" by 13-3/8" annulus pressure in Granite Point wells No. 31-14 RD 2 and MUCI-2 on a daily basis during injection operations, to ensure the wells do not function as conduits for fluid migration. 6. Mobil Oil Company and UNOCAL are surface owners within cone-quarter mile radius of GP 44-11 and have been duly notified of the proposed plans. 7. GP 44-11 was drilled to a total measured depth of 12208', equivalent to 11343' true vertical depth. Disposal Injection Order Ni~10 ~ Page 2 June 16, 1995 8. UNOCAL proposes to plug back the GP 44-11 well to 7800' measured depth. 9. The Upper Tyonek Formation is present within the GP 44-11 wellbore from the proposed plug back total depth to above 3000' measured depth. 10. The Upper Tyonek Formation consists primarily of interbedded siltstone, mudstone, coal, and lenticular sandstone. The sandstones, in general, are laterally discontinuous and comprise a low volume formation. Impermeable lithologies dominate the Upper Tyonek Formation. 11. Sandstones that are continuous throughout the vicinity of the GP 44-11 wellbore are present in the 4380'-4500', 5100'-5500', and 5900'-6300' measured depth intervals. 12. The proposed disposal injection zones are in the S 100'-5500', and 5900'-6300' measured depth intervals in the GP 44-11 wellbore. 13. The portion of aquifers beneath Cook Inlet described by a one quarter-mile area beyond and lying directly below the Granite Point Field are exempted for Class II injection activities by 40 CFR 147.102(b) (2) (A) and 20 AAC 25.440 (c). 14. Athree-dimensional hydraulic fracture simulator run of a worst-case scenario with injection pressures exceeding the anticipated formation parting pressure, and using volumes of drill cuttings that surpass those expected for the GP 44-11 project, indicates induced fractures can not propagate more than 1100 feet vertically. 15. The disposed fluids are anticipated to be contained below a true vertical depth of 3850' within the Upper Tyonek Formation, based on worst-case fracture modeling. 16. In well GP 44-11, 13-3/8" surface casing string is set at 4019' measured depth and cemented with 2400 sacks of cement. 17. Nine and 5/8" casing is set at 7962' measured depth and cemented with 1800 sacks of cement. 18: UNOCAL proposes to install a string o~ 3-1/2" tubing with a packer set at 5030' measured depth. 19. UNOCAL proposes to run cement and casing evaluation tools in GP 44-11 to evaluate if the well can be successfully converted for disposal operations within the proposed disposal intervals. 20. Disposal fluids will consist of fluids associated with drilling, production, and workover operations. Typical fluids will include produced water, drilling and completion fluids, equipment wash water, drilling mud and cuttings, and NORM scale. 21. Maximum injection rate is expected to be 3000 barrels per day. Disposal Injection Order 110 June 16, 1995 Page 3 22. Estimated average injection pressure will be 2498 psi and estimated maximum injection pressure will be 3500 psi. 23. UNOCAL plans to monitor the 9-5/8" by 13-3/8" casing annulus pressure of the GP 44-11 during injection operations and report results on the Monthly Injection Report. CONCLUSIONS: The approval of disposal injection operations at GP 44-11 will not jeopardize correlative rights. 2. Permeable strata that reasonably can be expected to accept injected fluids at pressures less than the fracture pressure of the confining strata are present in the interval from 5120' to 7800' measured depth in GP 44-11. 3. All USDWs in the Granite Point Field have been exempted for Class II injection activities. 4. Injected fluids likely will be contained below a true vertical depth of 3850' adjacent to the GP 44-11 wellbore. Fluids injected at GP 44-11 will consist of Class II waste generated from drilling, completion, and production operations. 6. Mechanical integrity of the tubing, packer and 9-5/8" casing must be demonstrated in GP 44-11 prior to commencing injection operations, in accordance with 20 AAC 25.412. 7. Annulus pressure monitoring of GP 44-11 and surrounding wells is appropriate. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Infection Strata for Disposal. Class II oiI field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for the purpose of disposal into the Tyonek Formation interval from 5120' to 7800' measured depth in well GP 44-11. Rule 2 Demonstration of Tubing/Casin~ Annulus Mechanical Integrity The tubing/casing annulus must be tested prior to injection and every four years thereafter for mechanical integrity in accordance with 20 AAC 25.412. UNOCAL must demonstrate GP 44-11 contains sufficient volume of cement and/or adequate cement bond and mechanical integrity in accordance 20 AAC 25.030 and 20 AAC 25.412 prior to initiation of injection operations. Rule 3 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Disposal Injection Order No. 10 June 16, 1995 Page 4 Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 4 Annulus Pressure Monitorine The 9-5/8" by 13-5/8" annulus pressure in Granite Point wells 44-11, 31-14 RD2 and MUCI-2 will be monitored daily during injection operations and reported monthly on the "Monthly Injection Report" AOGCC form 10-406. Rule 5 Administrative Action Upon request, the Commission may administratively revise and reissue this order upon proper showing that any changes are based on sound engineering practices and will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated June 16, 1 Russell A. Douglass, Babcock, Commissioner AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 p.m on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. 'fhe Commission shall gratrt or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30 day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). INDEXES `~ Plot Pressure & Rate vs Time -Well GP 31-14RD2 aoo 350 300 -_ ~„ i r 250 - l " 9 5 8 4 13 3/8" 20" ~ ~ Tubing i_____ N 200 a tso t o0 so o ~ / ` ~ ro 0 o M ro oo w ro 0 0 0 0 M ~ m c~ O O O N \ N N ~ w m w m o~ m m m rn rn rn m rn rn rn rn m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ m ~ v n o c~ ~ m a ~ o r~ co rn ~ a N N N M O_ O O N N N O O N N N N N N ~ ~ ~ ~ N N ~ O O O O O O O O O O O O rn 0 r O N O rn rn w rn m 0 0 0 0 0 o in <n rn N N N N N N N O O O O O m 0 ~ N N O m 0 co N N O Date 7" 9 518" 13 3/8" 02/28x09 30 295 345 02/27/09 30 290 345 02/26/09 30 290 345 02/25/09 30 29C 345 02/24/09 30 290 345 02/23/09 30 290 345 02/22/09 30 290 345 02/21 /09 30 290 345 02/20/09 30 290 345 02/19/09 30 29G 345 02/18/09 30 290 345 02/17/09 30 290 345 02/16/09 30 290 345 02/15/09 20 290 345 02/14109 20 290 345 02/13/09 20 290 345 02/12/09 20 290 345 02/11 /09 20 ~ 290 345 02/10/09 20~ 290 345 02/09/09 20 290 340 02/08x09 20' 290 345 02/07/09 2 290 340 02/06/09 20 290 340 02/05/09 25 290 340 02/04/09 2 290 340 02/03/09 0 290 340 02/02/09 0 290 345 02/01/09 30 290 345 01/31x09 30 290 345 01/30/09 30 290 345 01/29/09 30 295 345 01/28x09 30 295 345 01/27/09 30 295 345 01/26/09 30 295 345 01/25x09 30 295 345 01/24/09 30 295 345 4/20/2009 3:16 PM - TIO Reports 7e.xls TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 11/30/2008 to 02/28/2009 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2009-02.x1s GP 31-14RD2 0 30 0 30 Plot Pressure & Rate vs Time -Well GP 31-14RD2 aoo 350 300 7.. 250 ~9 5/8" 13 3/8" ` i 20" a> 3 -Tubing) N 200 d a` 150 100 50 o m ro ro w m m o~ m ao ro ro ro m m m o~ w m m ro ro m rn rn rn m m rn rn m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M (D Q~ N In W ~ V I~ O ~ N O~ N ~ N ~ V n O N N of V O M c0 O~ (") O O O N N C7 O O O ~ N N N (h O O O _ ~- N N N N \O ~ ~ ~ ~ r r r ~ r r r r ~ .- r ~- ~ r ~ ~ ~ ~ ~ ~ ~ ~ O O O O O O O O O Date 7" 9 518" 13 318" 2 0" ~ -~ ~ 01 /31 /09 30 290 345 0 ~ : ' _ '.'~ . 01 /30/09 30 290 345 0 ~ 01/29/09 30 295 345 0 ~' 01 /28/09 30 295 345 0 ~~ 01 /2T09 30 295 345 0 01 /26; Oq 30 295 345 0 01/25,'09 30 295 345 0 01/24+u9 30 295 345 0 01/23.09 30 300 345 0 01/2209 30 300 345 0 01/21/09 30 300 345 0 01 /20.09 30 300 345 0 01/19/09 20 300 350 1 01/18/09 20 300 350 1 ,~., 01/17/09 25 300 345 2' . 01/16/09 25 300 345 0 01/15/09 20 290 345 0 01/14:'09 25 300 345 0 01/13,C~~ 20 290 345 0 01/12 J9 20 290 340 0 01/11;09 20 290 340 0 ' 01/10/09 20 290 340 0 1-, 01/09/09 20 290 340 0 01/08/09 20 290 340 0 01/0709 20 290 340 0 01 /06:'09 20 290 340 0 - 01/05~G9 20 290 340 0 01/049 20 290 340 0 01/03'09 20 290 340 0 01/0209 20 290 340 0 01101'09 20 290 345 0 ' 12/31108 20 290 345 0 12/30/08 20 290 345 2 ' ~ 12/29/08 0 295 345 2 ' 12/28/08 0 296 345 2 12/27/08 345 2 - 4/20/2009 3:16 PM - TIO Reports 7e.xls TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 10/31/2008 to 01/3112009 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2009-01.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 aoo 350 - 300 7" ~9 5/8" 250 13 3/8" t 20" ~, ~_Tubing. N 200 d a 1so I 100 so 1 0 0 0 o O O O O O O o 0 0 0 0 0 0 0 0 0 0 0 o O o 0 0 0 0 0 0 0 V I~ O M t0 O N N ~ (`~ O Q1 N ~ W r ~ 1~ O M O Q1 N iP W ~ d' r O O O O N N N M O O O N N ~ (') O O O N N M O O O O O O O O O O O N N N N N N N N N Date 7" 9 5!8" 13 3/8" 20" T ubing 12/31x08 2G 290 345 0 30 12/30108 20 290 345 2 35 12/29/08 0 295 345 2 12/28/08 0 295 345 2 12/27108 0 295 345 2 12/26/08 0 295 345 2 12/25/08 20 300 345 3 12/24/OS 20 300 345 3 12/23/08 20 300 345 3 12/22 OS 20 30G 345 3 12/21; 08 20 300 345 3 12/20108 20 300 350 3 12/19/08 20 300 350 3 12/18/08 20 300 345 3 12/17/08 20 30G 340 3 12/16/08 20 300 345 3 12/15/08 0 300 345 4 12/14/08 0 300 345 4 12/13/08 0 300 345 4 12/12/08 0 300 345 4 12/11/08 0 300 345 4 12/10/08 0 300 345 4 12/09.08 0 300 345 4 12/08/08 20 300 350 4 35 12/07/08 20 300 350 4 35 12/06/08 0 300 350 4 35 12/05/08 0 300 350 4 35 12/04/08 20 30G 345 2 35 12/03/08 20 300 345 2 35 12/02/08 20 300 345 3 30 12/01!08 20 300 345 3 30 11/30/08 20 300 345 4 35 11/29x08 20 300 345 4 35 11 /28/08 20 300 345 4 35 11/27/08 20 300 345 4 35 11/26108 30 300 345 4 35 TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 10/01 /2008 to 12/31 /2008 4/20/2009 3:16 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-12.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 aoo 350 - 300 I ~ ' I ~9 5/8" 250 13 3/8" -° 20" d Tubing y 200 d a 1so 100 so 0 0 o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M tD m N ~ ~ V O M (O O N N ~ V t` O N N ~ V O M (O m ("l O O O N N N M O O O N N N C7 O O O _ N . ~ .. ao rn rn rn m rn rn rn rn m rn o 0 0 0 0 0 0 0 0 0 ~ ~ ~ - 0 0 0 0 0 0 0 0 0 0 0 ~ ~ ~ ~- ~ ~ ~ ~ ~ r- ~- ~ ~ ~ ~ ~ ~ ~ ~ - Date r• s sia° 13 3/s'• so° ;;~ TIO Report 11/30!08 20 300 345 _ 4 ~' 11/29/08 20 300 345 4': 1 .~, Data Sheet 11/28!08 20 300 345 4 „~ ~_` .. ~~^y~-. 11/27/08 20 300 345 4i~~-~~ ~ ~ ~ ~ 1 v2sloa 30 300 345 a ~~ .~ ~. ~ ' GP 31-14RD2 11/25/08 20 300 345 4 '"'' ' ~~ w 11/24/08 20 300 345 _ 4 ~~ 11/23!08 20 300 345 4 GAS LIFT 11/22!08 20 300 350 4 11/21!08 20 300 350 4 11/20~Q8 20 300 350 4 Pe~mlt # 1002660 11/19!08 20 300 350 4 11/18!08 20 300 350 4 11/17!08 20 300 350 4 Sundry # 398-200 11/16/08 30 300 350 4t' 11/15!08 30 300 350 4 11/14!08 30 300 350 a API # 50-733-10061-02 11/13!08 30 300 350 4 11/12/08 30 300 350 2 11/11!08 30 300 350 2!: ~ > 08/31/2008 to 11130/2008 11 /10/08 30 300 350 2 ~: 11/09/08 30 300 350 2 11/08/08 30 300 350 2`. 11/07/08 30 300 350 4 11/06/08 30 300 350 4 11 /05 ~ 1~ 8 30 300 350 4 11/041(; t1 30 300 350 4 11 /03: D 5 30 300 350 4 11/02/08 30 300 350 3 ... 11/01/08 30 300 350 31 a ~ ~ ~ ~ +- 10/31 S" 30 300 350 3 "+~; ` 10/30~1~t~ 30 300 350 3 10/2& lr; 30 300 350 3 : ` 10/28.08 30 300 350 ~ 3 a• '_ 1~' #~',; 10/27!08 30 300 350 3 d~ ' *'"'~'. 10/26!08 30 300 350 4~.+; WSiyu. 4/20/2009 3:16 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-11.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 aoo 350 - 300 7~~ ~ 250 ~9 5/8" 13 3/8" 20" ` Tubing N 200 d a 150 100 50 ~- 0 w ro ro m m m m ro ro ro m m m m m m m m m m m m m ro ~ w ro m m m m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M (D ~ N N W ~ V 1~ O N ~ ~ V O ('~l f0 O N In ~ d f~ O (`~ O O (\ O O O N N N M O O O N N N N O O O N N N N O r m m w w eo ao ao m m m m m m m m rn rn m rn rn o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ Date 7" 9 5/8" 13 318" 20" Tubing 11/01/08 30 300 350 3 35 10/31 /08 30 300 350 3 35 10/30/08 30 300 350 3 10/29/08 30 300 350 3 10/28/08 30 300 350 3 10/27/08 30 300 350 3 10/26/08 30 300 350 4 10/25/08 30 300 350 4 10/24108 30 300 350 4 10/23/08 30 300 350 4 10/22/08 30 300 350 4 10/21 /08 30 300 355 4 10/20/08 20 300 350 10 10/19/08 20 300 350 10 10/18/08 20 300 350 10 10/17/08 20 300 350 10 10/16/08 20 300 350 10 10/15/08 20 300 350 9 10/141(18 20 300 350 9 10/13/08 20 300 350 9 10/1208 20 300 350 9 10/11,08 20 300 355 4 10/10/08 20 300 355 4 10/09/08 30 310 355 4 10/08/08 30 310 355 4 10/07/08 30 310 355 4 10/06/08 30 280 360 4 10/05/08 30 300 360 4 10/04/08 30 300 360 4 10/03/08 30 300 360 4 10/02108 30 300 360 4 10/01108 30 300 360 4 09/30/08 30 300 360 4 09/29/08 30 300 360 4 09/28/08 30 300 360 4 09/27/08 30 300 360 4 4/20/2009 3:15 PM - TIO Reports 7e.xls TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 07/31 /2008 to 11 /01 /2008 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-10.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 400 350 300 ~~~ -9 5/8" 250 13 3/8" 20" ) ~ ~-Tubing 200 w d a 150 100 50 _ .. 0 ao 0 o (") co 0 co o~ w m 0 0 0 0 M ~ rn N O O O ~ r n r is 0 0 0 0 ao m m eo m m m m 0 0 0 0 0 0 0 0 N ro v o cv ~n ~ '- N N N M O O ~ ~ r r r r ro ro 0 0 0 0 0 0 0 0 m m w co m m w eo m m m 0 0 0 0 0 0 0 0 0 0 0 o~ ~ n o ~ ~ m a ~ O ~- ~ ~ N N N N O O O ~ m m m m ro m rn w 0 0 0 0 0 0 0 0 0 o~ w m ao co m m 0 0 0 0 0 0 0 o M ~o rn N ~ ~ ~ f' r' N m m rn rn m - 0 0 0 o c -. Date 7" 9 518" 13 318" 20" Tubing 09/30%OS 30 300 360 4 40 09/29/08 30 300 360 4 40 09/28/08 30 300 360 4 40 09/27/08 30 300 360 4 40 09/26/08 30 300 360 4 40 09/25108 30 300 360 4 40 09/24/08 30 300 360 4 40 09/23/08 30 300 360 4 40 09/22/08 30 310 360 4 40 09/21/08 30 310 360 4 40 09/20/08 30 310 360 4 40 09/19/08 30 310 360 4 40 09/18/08 30 310 360 4 40 09/17/08 30 310 360 4 40 09/16/08 30 310 360 4 40 09/15/08 30 310 360 4 40 09/14/08 30 310 360 4 40 09!13%08 30 310 360 4 40 09/12/08 30 310 360 4 40 09/11 /08 30 310 360 4 40 09/10;r~; 30 310 360 4 40 09/09,')r 30 310 360 4 40 09/08-0; 30 32G 360 4 40 09/07/08 30 310 360 4 80 09/06rOB 30 310 360 4 80 09/05 08 30 310 360 4 80 09/04n?>> 30 310 360 4 80 09/03/08 30 310 360 4 40 09/02/08 30 310 360 4 40 09101 /08 30 310 360 4 40 08/31 !08 30 310 365 4 40 O8/30108 30 310 365 4 40 08/29/08 30 320 360 4 40 08/28/08 30 320 360 4 40 08/27/08 30 320 360 4 40 08/26/08 30 320 360 4 40 4I20I2009 3:15 PM - TIO Reports 7e.xls TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 06/30/2008 to 09/30/2008 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-09.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 aoo 350 300 i _ 7.. I, 250 ~9 5/8" 13 3/8" 20" ~% -Tubing!. a 200 d a 1so 100 so o ~~~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M co m _A v_> m v o m ~ `m ~_ ~n _ro `v r o N N ib _a r; o M co m O O N N N t+l O O O N O O O O N N N N ca ~ ~ co cn ifl cn ~ iD ~ ~ n n r ~ ~ n r~ w m oo w m m m w w o`~ ..- ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Date 7" 9 5/8" 13 3/8" 20" 08/31!08 30 310 365 4 08/30/(~fi 30 310 365 4 08/29!08 30 320 360 4 08/28,Ur, 30 320 360 4 08/27 ~~~< 30 320 360 4 08/26r~~~ 30 320 360 4 08/2510+ 30 310 360 4 08/24, 0;, 30 310 360 4 08123!DP, 30 310 360 4 08/22;Ot? 30 310 360 4 08/21/0~1 30 31U 360 4 O8/20;`!a 30 310 360 4 08/19 '?`~ 30 310 360 4 08/18 ` ° 30 310 360 4 08/17,0:.: 30 310 360 4 OS/16~08 30 310 360 4 08/15/08 30 320 360 4 08/14~(~f'. 30 320 360 4 08/13/08 30 310 365 3 OS/121!,t; 30 310 365 3 OS/11:~.;a 30 310 360 3 OS/10 C'"'~ 30 310 360 3 08/09:: 30 310 360 4 08/08;1'~1~ 30 310 360 4 08/07C~~ 30 310 360 4 08/06,(i', 30 310 360 4 08/05i9F3 30 310 360 4 08/04/08 30 310 360 4 08/031nr~ 30 310 360 2 08/02:!.'^~ 30 310 360 30 08/01 f `", 30 310 360 30 07/31-G: 30 310 360 4 07/30: ~ + 30 310 360 4 07/29n1~> 30 310 360 4 07/28/08 30 310 360 4 07/27/08 30 310 360 5 Tubing 40 4U 40 40 40 40 40 TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 05/31/2008 to 08/31/2008 4/20/2009 3:15 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-08.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 .~..~~,,.-,.. .,..... ~.~._..r. x _, .~._.. . 350 300 0 25 ~ ~ 7" " i ~9 5/8 ~ 200 i 13 3/8" m r a` 20" -Tubing 150 - 100 50 O o o O o 0 0 0 0 0 o O O o 0 0 0 0 0 0 o O o 0 0 0 0 o O O o O M tp m N ~ OJ V f~ O N N ~ O !~ O M tp ~ N N of V O M (D O~ M O O O N N N M O O O N N N N O O O N N 7 N N N N ~!J Y1 N ~ N ~ (O t0 (O (D tp tD [O [p (p (D t` r r O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O ~. Date 7" 9 518" 13 318" 20" Tubing 07/31/08 30 310 360 4 40 07/30/08 30 310 360 4 40 07/29/08 30 310 360 4 07/28/08 30 310 360 4 07/27/08 30 310 360 5 07/26x'08 30 310 360 5 07/25/08 30 310 360 5 07/24/08 30 310 360 5 07/23/08 30 310 360 5 07/22/08 30 310 360 5 07/21/08 30 310 360 5 07/20/08 30 310 360 5 07/19/08 30 310 360 4 07/18/08 30 310 360 4 07/17/08 30 310 360 4 07/16/08 30 300 360 4 07/15/08 30 300 360 4 07/14/08 30 310 360 4 07/13/08 30 310 360 4 07/12/08 30 310 360 4 07/11/08 30 310 360 4 07/10/08 30 310 360 4 07/09.08 3G 310 360 3 07/08/08 30 310 360 0 07/07/08 30 310 360 0 07/06/08 30 310 360 3 07/05n~8 25 310 360 4 07/04,08 25 310 360 4 07/03; 08 25 310 360 4 07/02/08 25 310 360 4 07/01/08 25 310 360 4 06/3008 0 310 360 2 06/29%08 0 31G 360 3 06/28/08 0 305 355 3 06/27/08 0 310 355 3 06/26108 0 305 360 3 4/20/2009 3:14 PM - T IO Reports 7e.xls TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 04/30/2008 to 07/31/2008 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-07.x1s GP 31-14RD2 n Plot Pressure & Rate vs Time -Well GP 31-14RD2 400 350 300 i __ 7.. 250 ~9 5/8" ' ' ~ 13 3/8" 20" I Tubing N 200 a tso too 50 o ~ _ - ._ n .-~~ _. O O O o 0 0 0 o O O O O O o 0 0 0 0 o O O O o o O O O o o O o M (O 6~ N N W ~ V r O M O m N N ~ ~ 7 1~ O N ~ W ~ V ~ O C'J t0 Q~ M O O O N N N M O O O N N N M O O O N N N N V a V V V V V V Q V ~ N N N N v1 N ~ N N c0 ~ t0 c0 ~ c0 cD cD cD cD O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O Date 7" 9 518" 13 3/8" 20" 06/30/08 G 310 360 2 06/2908 0 310 360 3 06/28/08 0 305 355 3 06/27/08 0 310 355 3 06/26/08 0 305 360 3 06/25/08 0 305 360 4 06/24~Ot> 0 310 360 4 06/23108 30 300 355 3 06/2210£3 30 300 355 3 06/21/0;3 30 300 355 3 06/20/08 0 300 355 3 06/19/08 0 300 355 3 06/18/08 20 300 360 4 06/17/08 20 300 360 4 06/16/08 30 300 350 4 06/15/08 30 300 355 4 06/14.08 30 300 355 4 06/13:1?' 30 300 355 4 06/12;11` 30 300 355 4 06/11-~,1 30 30G 355 4 06/10/08 30 300 355 4 06/09/08 30 300 355 4 06/08.'08 30 300 355 3 06/07/08 30 300 355 3 06/06/08 30 300 355 3 06/05/08 0 300 355 3 06/04 !'': 0 30U 355 3 06/03 (?` 30 300 355 2 06/02 5 + 30 300 355 2 06/01 [it 0 300 345 0 05/31/08 0 300 340 3 05/30/08 0 300 345 3 05/29/08 0 30G 350 3 05/28108 0 300 350 3 05/27108 0 300 350 3 05/26/08 0 300 350 3 40 40 40 TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 03/31/2008 to 06/30/2008 4/20/2009 3:14 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-06.x1s GP 31-14RD2 Tubing 40 40 Plot Pressure & Rate vs Time -Well GP 31-14RD2 350 300 250 '~ 7.' ~9 5/8" ~ 13 3/8" ~ 20" N200 -Tubing d ` a 1so 100 so o .. .,., . __ . ..,,.. ~,....W.-- 0 0 0 0 0 0 0 o O o o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O~ (`~ cD O~ N N W ~ V r O N N ~ ~ K I~ O (") (O m N N ~ ~ ? r O M cp C N N N ~ ~ ~ N N ~ r. ~i - N O O O _ c7 O O O N N_ O O O ~ - ~- i ;:J „" ^; M M M t~l Nl c"] M c'^ d' '? ~t K ? •S -t a ~S ? ~(J N ~~-: o c o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o c - _. ~' Date 7" 9 s/&'• 13 318•' so^ TIO Report 05/31 /O8 0 300 340 3 05/30/08 0 300 345 3 Data Sheet 05/29/08 0 300 350 3 05/28/08 0 300 350 3 05/27/08 0 300 350 3 GP 31-14RD2 05/26/08 0 300 350 3 05/25/08 0 300 350 3 05/24/08 0 300 350 3 GAS LIFT 05/23/08 0 300 350 2 05/22/08 0 300 350 2 ' ~' 05/21:08 30 300 350 3 ~ ~~ Permlt ~# 1002660 05/20r';~ 30 300 350 3 05/19r0o 30 300 350 3 ~`- "- 05/18:0;; 30 300 350 3 ~ Sundry # 398-200 05/1708 30 300 350 3 05/16/!!8 30 300 350 3 0511558 30 300 350 3 API # 50-733-10061-02 05/14, ~ r 30 300 350 3 05113,08 30 300 350 3 05/12;ui~ 30 300 350 3 02/29/2008 to 05/31/2008 05/11/08 30 300 350 3 - 05/10iG8 30 300 350 3<- ~ 05/09,0£3 30 300 350 3 05/08iU8 30 300 350 3 05/07/0£3 30 300 350 3 ~_• 05/06/08 30 300 350 3 + ' 05/05/08 30 300 350 0 05/04;~~8 30 300 350 0 05/0328 30 300 350 0'' 05/02:'08 30 300 350 0 05/01;!"~~S 30 300 350 3 04/30 ?£ 30 300 350 3 04/29'08 30 300 350 3 04/28/08 30 300 350 3 04/27;'08 30 295 350 3 04/26!08 30 300 350 3 4/20/2009 3:14 PM - TIO Reports 7 e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-05.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 400 350 300 ~~, -9 5/8" 250 13 3/8" - 20" 200 -Tubing ~ a i d ` a 1so 100 so 0 ~ ~ r~ r r r r ~ r m m m m o~ ao co m co m m m m co w ro w m co m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O M cD O~ N N W ~ V I~ O N N ~ V f~ O M O O ~ V t~ O M <D O~ N N N M O O O ~ ~ ~ N N N M O O O N N N N O O O ~ r' ~ ~ N N N N N N N N N N N N N ~ ~ N N N N N N N N N N r ~ r r r r r .- .- O O O O O O O O O O O O O O O O O O O O Date 7" 9 5/8" 13 3/8" 20" Tubing 02/29/08 30 290 345 0 40 02/28/08 30 290 345 0 40 02/27rC~s 30 290 345 0 40 02/26i';e 30 290 345 0 40 02/25!G:', 30 290 345 3 45 02/241ofs 30 290 345 3 45 02/23%r7P~ 30 290 345 3 45 02/22,OSS 30 290 345 3 45 02/21/03 30 299 345 3 40 02/20i01s 30 290 345 2 45 02/19/0£1 30 290 345 2 45 02118/u8 30 290 345 2 45 02/17-o,~s 30 290 340 2 40 02/16r'ti:; 30 290 340 1 45 02/15!i~~ 30 290 340 1 40 02/14~`~r, 30 290 340 0 40 02/13 i!': 30 290 340 0 45 02/12;(~~~, 30 290 340 0 40 02/11 n:- 30 290 340 0 80 02/10Ci`1 30 285 340 0 40 02/09 si-~ 30 285 340 0 40 02/08!!`: 30 285 340 0 40 02/07(„ 30 285 340 0 40 02/06:iv 30 285 340 0 40 02/05~OS 30 285 340 0 90 02/0408 30 285 340 0 90 02/03 C 30 285 340 0 40 02/02 Os 30 285 340 0 40 02/01'0t' 30 285 340 0 40 01/3vri~, 35 285 340 0 45 01/301'` 30 285 340 2 45 01 /29!s it; 30 285 340 2 45 01/28/08 30 290 340 2 50 01/27/!ifs 30 290 340 2 50 01/26IOt~ 30 290 340 2 50 01/25/Uf'~ 30 290 340 0 50 TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 11/30/2007 to 02/29/2008 4/20/2009 3:13 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-02.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 ~~ aoo ~ r 350 - 30 0 ~~• ~9 5/8" 250 13 3/8" f 20" y Tubing _ ___. ___ .__-_ w 200 d d 150 1 00 50 0 n r r r ~ r r w m oo m m ~ ~ m m m r r n r r r n r r r r n ~ n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 D m N In ~ ~ M lD O] N iP 0p ~ 'Q I~ O N to h ~J O M O l t V l0 ~ W V O O O N N N_ O O O N N J m O O O N N N M r r r ~ r r r ~ r r r ~ r r r r ~ ~ ~ O O O O O O O O O O Date 7" 9 518" 13 3/s" so° ~ ~~ ~ TIO Report 01/31/08 35 235 340 0'~ `. ,+ Data Sheet 01/30/08 30 285 340 2 N~ 01/29108 30 285 340 2 45 01/28/08 30 290 340 2 56 01/27/08 30 290 Sao 2; GP 31-14RD2 01/26/08 30 290 340 2s , 01 /25108 30 290 340 0 ~ ~~'~- '• 01/24/08 30 290 340 0e' ~ ~'~,, ~'~ GAS LIFT 01 /23/08 30 290 340 0 01 /22/08 30 290 340 0 01/21/08 30 290 340 0` ~ Permit#1002660 01/20/08 30 290 340 0 01/19108 30 290 340 0: ov18;o8 30 290 Sao ot . - ~ ., Sundry # 398-200 01/17;oE~ 0 290 340 0 , 01/16C~is 30 290 340 0 ov15 ~:~~~~ 35 285 338 o API # 50-733-10061-02 01/14!:!6 40 285 340 0 01/13~C8 40 290 340 0 01/12/08 40 290 Sao 0 11/01/2007 to 01/31/2008 01/11/08 40 290 340 0 01/10;08 40 290 340 0 01/09!n8 40 290 340 0 01/08:08 40 290 340 0 01 /07; n 8 40 290 340 0 01/06 n;- 35 290 345 0 01/05:!?: 35 290 345 0 01/04('a~ 40 290 345 0 01/03,(it 40 290 345 0 01/02'0!_1 40 290 345 0 01/01:0£1 40 290 345 0 '~~- 12/31 X07 40 290 340 0 12/30/07 40 290 340 0 12/29!07 40 290 340 0 12/28/07 40 290 340 0 12/27/07 40 290 340 0 4/20/2009 3:12 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-01.x1s GP 31-14RD2 aoo 350 300 7'• ~9 5/8" 250 13 3/E --° 20" m ~Tubirn N 200 d ` a 1so 100 so V~ o~ 0 O t\ O Date 12/31 /07 12/30/07 12/29/07 12/28/07 1 z/z7/o7 12/26/07 12/25/07 12/24/07 12/23/07 12/22/07 12/21 /07 12/20/07 12/19/07 1 z/1 aro7 12/17/07 12/16/07 12/15/07 12/14107 12/13/07 1 zn z/o7 12/11/07 12/10/07 12!09/07 12/08/07 12/07/07 12/06/07 12/05/07 12/04/07 12/03/07 12/02/07 12/01 /07 11 /30/07 11 /29/07 11 /28/07 11 /27/07 11 /26/07 4/20/20 Plot Pressure & Rate vs Time -Well GP 31-14RD2 r r r~ 0 0 0 M n n n 0 0 0 N i 0 n n ~ 0 0 0 n 0 0 0 0 ~ ~ n n ~ ~ n ~ ~ ~ r 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C f~ O M t0 Q> N N ~ 0 <p O~ O O O O O O n o ~ ~ ~ O O O O f~ N N N O O O ~ ~ f O N N M O O O O f ~ f f ~ ~ ~ O f~ O M t m N N N N O O O ~ ~ ~ N N N N ~ ~ ~ N N N N N N N N N N r' s s~s^ 13 318" so ° ~ TIO Report 40 40 290 290 340 340 Od,~ ~ =';'_; ~~ O l,r _ ,:~~ : _' (]at8 Sheet 40 290 340 ~ 0 ao 290 340 o GP 31-14RD2 40 290 340 0 40 290 340 2 ao 290 Sao 2 GAS LIFT 4G 290 340 3 40 290 340 3 ao 2so :340 3 Permit # 1002660 40 290 340 3 40 290 340 3 40 290 340 3 Sundry # 398-200 40 290 340 3 40 290 340 3 40 2so Sao 3 API # 50-733-10061-02 40 290 340 2 40 ao 290 290 340 Sao 2 2 09/30/2007 to 12/31/2007 40 290 345 3 40 290 345 3 ao 290 345 3 45 290 345 3 45 290 345 3 45 290 345 3 45 290 345 3 45 290 345 3 40 300 350 3 40 300 350 3 ao 300 350 3 ao 300 350 3 40 300 350 3 47 300 350 3 47 300 350 3 45 300 350 3 )9 3:11 PM - T IO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2007-12.x1s GP 31-14RD2 soo soo aoo d N 300 d 6 a zoo ioo a n n n n n n n n c8 n 0 in th O N n n n n n 0 0 0 0 0 c:i ~ m O O ~_ ~ ~ ~ n n 0 0 v N N n 0 n N n 0 o ~ n n n 0 0 0 cv ~'n is O O O N N N n n n n n n n n 0 0 0 0 0 0 0 0 ~ o n o ro co Q ~ ~ r- N N N O O N N N N N N (~] M O O O O n 0 0 0 0 0 0 0 0 0 n o ~ ~ m A ~n m O ~ ~ ~ ~ N N N O`) t7 M M N1 M M (`') t~ (7 O O O O O O O O O O O O O O O O O O O O O O O O O O Date 7" 13 318" 20" Tubing TIO Report 03/3110;' 80 330 0 80 Data Sheet 03/30/C' 80 •, 330 o eo 03/29/0 i 80 330 0 8~; 03/2810 r' 80 330 0. $5~ 03/27/0% ao 330 0 ~6' GP 31-14RD2 03/26/0 i 70 , , ~-__ -., 330 0 $~ 03/25/0 ~ 70 ~yC~ 330 0 ~~~ o3/2a/c? 70 ~:, 330 o a~ GAS LIFT 03/23/0? 75 29'~ 329 0 /Q~ 03/2210 i 7~ ~9C, 328 0 801 03/21107 ~ 2$~ ~ "" 328 0 8011 permit # 1002660 03/20/07 75 ~ ~ ~~ 328 0 80t 03/19/07 80 ~ 2 328 0 SSI o3/1a/o? ao ~7r~~ 325 0 9~~ Sundry # 398-200 03/17P~ % 8n £'yC~` 325 0 !90 03/1610 i 80 T;t, 32s 0 90 o3/1s/o? ~:~; ~,~e,- 3zs o 901 API # 50-733-10061-02 03/14/07 i~~ 78(++: 325 0, 90 03/13!07 8C ?8:0' ' 325 0 90~ 12/31/2006 to 03/31/2007 o3/1zro? su 2a:> 32s or ~ 03/11/07 8G i3r° 32s 1 ~ ~ ~ ~ ~ 03/10/07 F;0 ?911 330 0 ~.~ ~ ,°< _ 03/09/07 St' 2~3`; 32s 1 ~ ~' ~~~' 03/08107 ?.D 2$(~ 325 0?~ ~y;_,-,a: r ~~ ti.. 03/07/0T 80 t°.. 325 1 ~ `~ 03/06/0? 7'S ~8',- 325 1 ~~~~~ 03/05101 03/0410.7 8C ?.85 9C 28`' 228 330 0 0 ~ ~ >A 03/03/0' 9n 28G 330 0 90 03/02/Oi 90 2~tj 330 0 90: 03/01/07 90 -2317. 330 0 90 02/28/07 9ci ?>8~5 330 0 90• 02/27/0 / 9U 25€` 330 G 90- 02/26/07 9~` ?tat) 330 0 90` 02/25/07 7 SC' 28ei, 80 B~~ 330 330 2 2 90" 90;1 02/24/0 12!31/2007 9:12 AM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt GranitePt_Unocal_2007-03.x1s GP 31-14RD2 Plot Pressure & Rate vs Time -Well GP 31-14RD2 • • Pres sure O N O O W A O O ~ O O O 10/31 /06 :> 11 /03/06 11 /06/06 ' I I I 11 /09106 ' ~ No w ~ ~ ~ w ~ 11 /12/06 ' ~ 11/15/06 11 /18/06 ~ '^ ~ 11121 /06 ~ ' G 's , Y ~"~ ' ~ ~ 11 /24/06 11 /27/06 a v' C 11 /30/06 ' ~ 12/03/06 Qo 12/06/06 , 12/09/06 s ~ 12/12/06 v' 12/15/06 ~ ~' 12/18/06 ~ ~ 1 12/21 /06 ~ ~i ~D 12/24/06 ' C 12/27/06 b 12/30/06 'A W ~-- i 1 /02/07 ~ ~` 1 /05/07 1 /08/07 ' N 1/11/07 1 /14/07 1 /17/07 1 /20/07 1 /23/07 1 /26/07 1 /29/07 • • Plot Pressure & Rate vs Time -Well GP 31-14RD2 600 ~„,~_ ,~~., .~W ..._.~ ~ ,~ ~.~~~..~~,, . _....._a.r .~m~~~ .~~ ~ ~._. ~ . a . _ ~ ~,~ . ~. , ~ - - - _ ~ _ ..~ v_.__, __ ._. _ ~„ ~9 5/8" 500 13 3/8"' ~~20~~ Tubing 400 d L N 300 L a Zoo 100 co 0 co co m co cfl 0 0 0 0 0 co co cg co cp cfl co co co ca co cfl co m co co co co 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co 0 m co co 0 0 0 cg co co 0 0 M O C~ O N t[) oD O ~ ~ r O ~t I~ O N ~ W ~ ~ n O M O O N ~ W N N N Ch O O O ~- T ~ N N N N O O O ~ ~ r A O M N N O N O ~ N O pp O pp pp ap op c~ ao op op c0 p) O) ~ O) cT O) O) ~ O) ~ O O O O O O O O O O ~- O CJ O 1 O O _ CS O Pressure N N W l O CJl O O O O W ~ CJl O O O 10/03/08 10/06/08 10/09/08 10/ 12/08 -- 10/15/08 10/ 18/08 ( I 10/21 /08 ~ N ~ ~ ~ ~ ' 10/24/08 ~ w - I 10/27/08 ~ w 10/30/08 ~ 11 /02/08 11 /05/08 11 /08/08 ~ 11/11/08 ~' 11 / 14/08 ~ 11/17/08 ~ ~ 11 /20/08 -~ 11 /23/08 ~ 11 /26/08 ' 11 /29/08 12/02/08 ~ CD 12/05/08. ~ ~y, tG" 12/08/08 12/11/08 -~ 12/14/08 ~ 12/17/08 '"r 12/20/08 12/23/08. rj~ 12/26/08 y 12/29/08 ~• 1 /01 /09 1 /04/09 ~D 1 /07/09 ~ ~ 1/10/09 1 /13/09 ~ 1 / 16/09 1 C 1 /19/09 1 /22/09 1 /25/09 ~ 1 /28/09 W 1 /31 /09 ~~ ~ 2/03/09 {{ 2/06/09 ~ 2/09/09 ~, 2/12/09 2/15/09 ' N 2/18/09 i 2/21 /09 ~ 2/24/09 2/27/09 3/02/09 3/05/09 3/08/09 3/ 11 /09 3/14/09 3/17/09 3/20/09 3/23/09 3/26/09 3/29/09 • • H ~1 G U I ~~ Plot Pressure & Rate vs Time -Well MUC 1-02 zoo zoo 1so 1eo 9 5/8" 13 3/8" 160 20° 160 Tubing Vol MUC2 140 140 120 120 N 100 1 d ` ~ a 80 80 60 - - 60 40 - 40 -- 20 20 0 0 ao 0 o M ~ o~ ao w o~ w w co 0 0 0 0 0 0 0 m ~ rn N ~ m O O O ~ ~ ~- N N N N N N N N ~ ~ ~ ~ r r ~ o~ w m rn rn m m rn rn rn rn rn rn m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 v n o cv ~n oo _ v n_ o M co m v N N (") O O O N N N N O O N N N ~ ~ ~ ~ ~ N N .- ~- ~ O O O O O O O O O O O O rn m 0 0 n o O ~ N N O O rn rn rn m 0 0 0 0 M ~ w c~ ~ ~ r' N N N N N O O O O rn 0 N N N O rn 0 ~ N N O Date 13 318" 20" Tubing vol MUC2 TIO Report 02/28/09 70 0 0 U 02/27/os 70 0 0 o Data Sheet 02/26/09 70 0 0 0 02/25/09 70 0 0 0 02/24/09 70 0 0 0 MUC I-02 02/23/09 75 0 0 0 02/22/09 75 0 0 0 02/21/09 75 0 0 o INJECTION 02/20/09 75 0 0 0 02/19/09 75 0 0 0 02/18/os 75 0 0 o Permit # 1690670 02/17/09 75 0 0 0 02/16/09 75 0 0 0 02/15/09 70 0 0 v API # 50-733-20193-00 02/14/09 70 0 0 0 02/13/09 70 0 0 0 02/12/09 70 0 0 0 11130/2008 to 02/28/2009 02/11/09 70 0 0 0 02/10/09 70 0 0 0 02/09/09 70 0 0 0 02/08/09 70 0 0 02/07/09 70 0 0 02/06/09 70 0 0 02/05/09 70 0 0 02/04/09 70 0 0 02/03/09 70 0 0 02/02/09 70 0 0 02/01/09 70 0 0 0 01/31/09 70 0 0 0 01 /30/09 70 0 0 0 01 /29/09 70 0 0 0 01/28/09 70 0 0 0 01/27/09 70 0 0 0 01 /26/09 70 0 0 0 01/25/09 70 0 0 0 01/24/09 70 0 0 0 4/20/2009 3:16 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2009-02.x1s MUC I-02 Plot Pressure & Rate vs Time -Well MUC I-02 zoo zoo tao tao ~9 5/8" 13 3/8" ^ 160 160 P0 -Tubing Vol MUC2 140 140 120 120 c v t w 100 d ` ~ a 80 80 60 60 40 40 20 20 0 0 ro ro m m m ro ~ ro w m m co m eo m m m ao m o~ ao rn m m rn rn rn m rn m rn 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ [p ~ N N N V I~ O (") N m N N ~ a ti O N N W 'cT r O M f0 m M O O O N N N M O O O ~ N N N (") O O O _ N N N N O ~ ~ ~ ~ ~ r r ~ ~ ~ r r ~ .- '- '- .-- ~ ~ ~ ~ .- ~ O O O O O O O O O O Date 13 3/8" 20" Tubing Vol MUC2 TIO Report 01/31/09 70 0 0 0 Data Sheet 01/30/09 70 0 0 o 01/29/09 70 0 0 0 01/28/09 70 0 0 0 01/27/os 70 0 0 o MUC I-02 01/26/09 70 0 0 0 01 /25/09 70 0 0 0 o1/2a/os 70 0 0 o INJECTION 01/23/09 70 0 0 0 01 /22/09 70 0 0 0 01/21/09 70 0 0 o Permit # 1690670 01/2o/os 70 0 0 0 01/19/09 50 0 0 0 01/18/os 50 0 0 o API # 50-733-20193-00 01/17/09 50 0 0 0 01/16/09 50 0 0 0 01 /15/09 50 0 0 0 10/31 /2008 to 01 /31 /2009 01/14/09 50 0 0 0 01/13/09 50 0 0 0 01/12/09 50 0 0 0 01/11/09 50 0 0 0 01/10/09 50 0 0 0 01 /09/09 50 0 0 0 01/08/09 50 0 0 0 01/07/09 50 0 0 0 01/06109 50 3 0 0 01/05/09 50 0 0 0 01 /04/09 50 0 0 0 01 /03/09 50 0 0 0 01 /02/09 50 0 0 0 01/01/09 50 0 0 0 12/31/08 50 0 0 0 12/30/08 50 0 0 0 12/29/08 60 0 0 0 12/28/08 50 0 0 0 12/27/08 50 0 0 _ 4. 4/20/2009 3:16 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2009-01.x1s MUC I-02 Plot Pressure & Rate vs Time -Well MUC I-02 400 200 180 350 -9 5/8" ~ 13 3/8" 20" 160 300 -Tubing Vol MUC2 140 250 --- 120 ~ a~ w 200 1~ d a so 1so so 100 40 ao - 20 0 0 0 0 0 0 0 o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 v ~ o_ _M co rn N ~ m M ~ m c~ ~ ro ~ v n o r> ~ rn N ~ m ~ v r o O O O N N N M O O O N N N M O O O ~ ~ ~ N N N M O O O O O O O O O O O ~ ~ N N N N N N N N N N Date 13 318" 20" Tubing Vol M 12/31/08 50 0 0 12/30/08 50 G 0 12/29/08 60 0 0 12/28/08 50 0 0 12/27/08 50 0 0 12/26/08 50 0 0 12/25/08 60 0 0 12/24/08 60 0 0 12/23/08 60 0 0 12/22/08 60 0 0 12/21/08 60 0 0 12/20/08 60 0 0 12/19/08 60 0 0 12/18/08 60 0 0 12/17/08 60 0 0 12/16/08 60 0 0 12/15/08 60 0 0 12/14/08 60 0 0 12/13/08 60 0 0 12/12/08 60 0 0 12/11/08 60 0 0 12/10/08 60 0 0 12/09/08 50 0 0 i 12/08/08 60 0 0 12/07/08 60 0 0 12/06/08 60 0 0 12/05/08 60 0 0 12/04/08 60 0 0 12/03/08 50 0 0 12/02/08 60 0 0 12/01 /08 60 0 0 11/30/08 70 0 0 0 11/29/08 70 0 0 11/28/08 70 0 0 11/27/08 70 0 0 0 11/26/08 70 0 0 0 4/20/2009 3:16 PM - TIO Reports 7e.xls TIO Report Data Sheet MUC I-02 INJECTION Permit # 1690670 API # 50-733-20193-00 10/01 /2008 to 12/3112008 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-12.x1s MUC I-02 Plot Pressure & Rate vs Time -Well MUC I-02 aoo zoo 180 350 9 5/8" 160 I i 13 3/8" 300 I " _ .., 20 -Tubing Vol MUC2~ 140 250 120 ~ ~00 d 1 Qg , d ~ a so tso so too ao so 20 0 0 0 o O o 0 0 0 o O O O o 0 0 0 0 0 0 0 0 0 0 0 0 0 o O O o 0 0 ch c0 m N ~ ~ ~ V f~ O M c0 T N N ~ ~ a !~ O N uJ W ~ 7 r O (`~ ~ ~ (~ O O O N N N CJ O O O N N N [7 O O O N N N N OJ m m ~ m m m m m O~ m O O O O O O O O O O \ O O O O O O O O O O O ~ ~ ~ .- ~ ~ r ~ ~ ~ ~ ~ ~ ~ '- ~ ~ ~ ~ ~ Date 13 3/8" 20" Tubing vol MUC2 TIO Report 11/30/08 70 0 0 0 11/29/08 70 0 0 Data Sheet 1 v2s/os 70 0 0 11/27/08 70 0 0 0 11/2s/os 70 0 0 o MUC I-02 11/25/08 70 0 0 0 11/24/08 70 0 0 0 11/23/08 70 0 0 o INJECTION 11/22/08 60 0 0 0 11 /21 /08 60 0 0 0 11/20/08 60 0 0 o Permit # 1690670 11/19/08 60 0 0 0 11/18/08 60 0 0 0 11/17/os so 0 0 o API # 50-733-20193-00 11/1s/os so 0 o v 11/15!08 60 0 0 0 11/14/08 so 0 0 0 08/31/2008 to 11/30/2008 11/13/08 60 0 0 0 11/12/08 65 0 0 0 11/11/08 65 0 0 0 11/10/08 65 0 0 0 11/09/08 65 0 0 0 11/08/08 65 0 0 0 11/07/08 65 0 0 0 11/06/08 65 0 0 0 11/05/08 65 0 0 0 11 /04/08 60 0 0 0 11 /03/08 60 0 0 0 11/02/08 60 0 0 0 11/01/08 60 0 0 0 10/31/08 60 0 0 0 10/30/08 60 0 0 0 10/29/08 60 0 0 0 10/28/08 60 0 0 0 10/27/08 60 0 0 0 10/26/08 70 0 0 0 4/20/2009 3:16 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-11.x1s MUC I-02 r~ Plot Pressure & Rate vs Time -Well MUC 1-02 200 200 1ao 1so ~9 5/8" 13 3/8" 160 ^ 160 20 -Tubing -Vol MUC2 140 140 120 120 d 7 N 100 0> 1~ a 80 - 80 60 60 40 40 20 20 0 0 m m m m m m m m m o~ w ro w m m m o~ m w ~ w m o0 0o m co m m o~ ao co w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M !p m N ~ ~ O I~ O N in ~ -S r O M O O> N N a0 V I~ O M U) m M O O O N N N t\ O O O N N N N O O O ~ '- N N N N O f~ ~ ~ ap ~ ~ ~ ~ ~ ~ W m ~ ~ Oi G~ O> O~ O~ O> O~ O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O ~ ~- ~ ~ ~ ~ Date 11!01 /08 10/31 /08 10/30/08 10/29/08 10/28/08 10/27/08 10/26/08 1 o/2s/oa 10/24/08 10/23/08 10/22/08 10/21 /08 10/20/08 10/19/08 10/18/08 10/17/08 10/16/08 10/15/08 10/14/08 10/13/08 10/12/08 10/11/08 10/10/08 10/09/08 10/08/08 10/07/08 10/06/08 10/05/08 10/04/08 10/03/08 10/02/08 10/01 /08 09/30/08 09/29/08 09/28/08 09/27108 20" Tubing voi nnucz TIO Report 0 o 0 : o 0 o Data Sheet 0 0 0 0 0 0 o o o MUC I-02 0 0 0 0 ~ 0 0 0 0 o INJECTION 0 0 0 0 0 0 0 0 o Permit # 1690670 0 ~ 0 0 0 0 0 0 0 o API # 50-733-20193-00 0 0 0 0 0 0 0 0 0 07/31 /2008 to 11 /01 /2008 0 0 0 3 0 0 3 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 0 0 ~ 0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4/20/2009 3:15 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-10.x1s MUC I-02 Plot Pressure & Rate vs Time -Well MUC I-02 200 200 180 180 ~9 5/8" 13 3/8" ~ , 160 160 mPO^ -Tubing -Vol MUC2 140 140 120 120 d d 1 N 100 d - ~ a 80 80 60 60 40 40 20 20 0 0 m m o0 0~ oo co m m w m w m w o~ ~o m ro w m ao m w eo m m ro m w w m w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o M o rn N in ~ v r= o <v ~n co v n o ~ co rn v ~ o m` co rn N N w (h O O O ~ ~ ~ N N N M O O O ~ ~ ~ N N N N O O O ~ ~ ~ ~ N N N co ~ ~ r ~ r~ ~ ~ n n ~ m ro m m co w w oo w m rn m rn rn rn m rn rn rn rn 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 13 318" 20" vol MUC2 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 70 0 0 0 70 0 0 0 70 0 0 0 70 0 0 0 70 0 0 0 70 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 ao 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 ao 0 0 0 so a o 0 TIO Report Data Sheet MUC I-02 INJECTION Permit # 1690670 API # 50-733-20193-00 06/30/2008 to 09130/2008 4/20/2009 3:15 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-09.x1s MUC I-02 Plot Pressure & Rate vs Time - Well MUC I-02 zoo zoo 180 180 9 5/8" 13 3/8" 160 160 20^ I Tubing -Vol MUC2 140 140 - 120 120 d d 1 N 100 d - - ~ a 80 ao 60 60 40 40 20 20 0 0 m ro o w o m m oo ro ~ m w co ro m w o~ m ao co m oo w m m m o~ m m ao m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M ~ rn N in o~ ~ v r o c%> co rn <~ in ro a n o N ~ o a r= o i~ cD m (h O O O ~ ~ ~ N N N M O O O ~ ~ ~ N N N M O O O ~ •- ~ N N N N ~n ~ o o cv m ~ ~ co ~ m n ~ n ~ n ~ ~ r n ~ ao m m ro m ~ o~ m m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Date 08/31 /08 08/30/08 08/29/08 08/28/08 os/27/os os/2s/os 08/25/08 08/24/08 08/23/08 08/22/08 os/2vos os/2o/os 08/19/08 os/1 s/os 08/ 17/08 08/16/08 08/15/08 08/14/08 08/13/08 08/12/08 08/ 11 /08 08/10/08 08/09/08 08/08/08 08/07/08 08/06/08 08/05/08 08/04/08 08/03/08 08/02/08 08/01!08 07/31/08 07/30/08 07/29/08 07/28/08 07/27/08 13 318" 20" 80 80 80 80 so so 80 so 80 80 so ao so ao 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 ~~ TIO Report Data Sheet MUC I-02 INJECTION Permit # 1690670 API # 50-733-20193-00 05/31/2008 to 08/31/2008 80 80 80 80 80 4/20/2009 3:15 PM - TIO Reports 7e.xls 0: 0 o~ o 0>. 0 0- 0 0` 0 o- o 0 0 o'? o 0` 0 0-' 0 0'' 0 0 0 o o 0 0 0 0 0 0 0 0 0' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0, 0 0' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0' 0 0 0 0 0 0 0 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-08.x1s MUC I-02 r~ Plot Pressure & Rate vs Time -Well MUC 1-02 zoo zoo 180 180 9 5/8" 13 3/8" 160 ^ 160 ..20 Tubing Vol MUC2 140 140 120 120 d 7 N 100 y 1~ ~ ~ a 80 80 60 60 40 40 20 20 0 0 w oo 0 0 m co m o~ o 0 0 0 0 0 ro ~ ~ w ~ m m m m m m o~ oo m ro m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m 0 m m m m m m m 0 0 0 0 0 0 0 o M (") O v in 0 0 co rn N N m O O .n ~n u`> in in 0 0 0 0 0 ~ v n o ni u~ m ~ o n o r~ co rn N ~ N N N [~ O O O N N N N O O ~n in in ~n co co co ~ co ~o co co co m r~ ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m O r 0 ~_ `v ~_ o ~ co rn N N N N n `r ~ ~ ~ ~ n 0 0 0 0 0 0 0 Date 07/31 /08 07/30/08 07/29/08 07/28/08 07/27/08 o7/2s/o8 07/25/08 07/24/08 07/23/08 07/22/08 07/21 /08 07/20/08 07/19/08 07!18/08 07/17/08 07/16/08 07/15/08 07/14/08 07/13/08 07/12/08 07/11 /08 07/10/08 07/09/08 07/08/08 07/07/08 07/06/08 07/05/08 07/04/08 07/03/08 07/02/08 07/01 /08 06/30/08 06/29/08 06/28!08 06/27/08 06/26/08 20" Tubing Vol MUC2 0 0 0 0 0 0 0 0 0 0 a o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 TIO Report Data Sheet MUC I-02 INJECTION Permit # 1690670 API # 50-733-20193-00 04/30/2008 to 07/31/2008 4/20/2009 3:14 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-07.x1s MUC I-02 Plot Pressure & Rate vs Time -Well MUC 1-02 zoo zoo 1ao - 1so ~~9 5/8" _-- 13 3/8" ~ 160 -~ 20^ 160 -Tubing Vol MUC2 140 ---.. 140 120 120 d N 100 m 1~ a 80 - 80 60 60 - 40 40 - -- ----------__------ - 20 20 0 0 o~ 0 M M O co 0 ('~ O a O ao 0 tD O a O 0o ao co ro oo 0 0 0 0 0 O~ N u1 ep O N V a a V V O O O O O ao ~ w ~ w w o~ w m m m ao co m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C I~ O r] O O> N ~ W V I~ O N ~ N N (h O O O N N N O O O 7 O V N in N N N N in N to ~ O O O O O O O O O O O O O O O O O ro 0 ~ O cD O m ro m ao 0 0 0 0 V I~ O ~ ~ ~ N tD <D t0 c0 O O O O w o~ 0 0 fh O N N t0 ~ O O o~ 0 O~ N ~ O Date 13 318" 20" Tub ing Vol MUC2 TIO Report 06/30/08 90 0 0 0 os/2s/os 90 0 0 o Data Sheet os/2s/os so 0 0 0 06/27/08 90 0 0 0 o6/2s/os so 0 0 o MUC I-02 06/25/08 100 0 0 0 06/24/08 90 0 0 0 06/23/08 90 0 0 o INJECTION 06/22/08 90 0 0 0 06/21 /08 90 0 0 0 06/2o/os 90 0 0 o Permit # 1690670 06/19/08 90 0 0 0 06/18/08 90 0 0 0 os/17/os so 0 0 o API # 50-733-20193-00 os/1s/os so 0 0 0 06/15/08 90 0 0 0 o6/1a/os 90 0 0 0 03/31/2008 to 06/30/2008 06/13/08 90 0 0 0 06/12/08 90 0 0 0 06/11/08 90 0 0 0 06/10/08 90 0 0 0 06/09/08 90 0 0 0 06/08/08 80 0 0 0 06/07/08 85 0 0 0 06/06/08 85 0 0 0 06/05/08 80 0 0 0 06/04/08 80 0 0 0 06/03/08 90 0 0 0 06/02/08 90 0 0 0 06/01 /08 90 0 0 0 05/31/08 80 0 0 0 05/30/08 80 0 0 0 05/29/08 80 0 0 0 05/28/08 80 0 0 0 05/27/08 80 0 0 0 05/26/08 80 0 0 0 4/20/2009 3:14 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-06.x1s MUC I-02 Plot Pressure & Rate vs Time - Well MUC I-02 200 200 180 180 ~~9 5/8" 13 3/8" 160 P0^ 160 -Tubing Vol MUC2 140 140 120 120 a 100 ~ ` 1~ ~ a eo - eo - so so qp 40 20 20 0 0 m 0 O) N N O m 0 fh O M O m m m m ~o 0 0 0 0 0 ~ m N N ~ O O M C7 fh t+1 ~ O O O O O m m o~ w m oo ao w w w w 0 0 0 0 0 0 0 0 0 0 0 C f~ O N ~ ap V I~ O N N N M O O O N M (`~ M M V V O V V V V O O O O O O O O O O O m w ao co o~ 0 0 0 0 0 M [O m N ~ N N N O O V 7 V in to O O O O O ao w m ao w w w m 0 0 0 0 0 0 0 0 W V r O M cD O~ O ~ ~ ~ N N N N N N N ~ N N ~ ~ O O O O O O O O Date 05/31 /08 05/30/08 05/29/08 05/28/08 05/27/08 05/26/08 05/25/08 05/24/08 05/23/08 05/22/08 os/21 /os 05/20/08 05/19/08 05/18/08 05/17/08 05/16/08 05/15/08 05/14/08 05/13/08 05/12/08 05/11/08 05/10/08 05/09/08 05/08/08 05/07/08 05/06/08 05/05/08 05/04/08 05/03/08 05/02/08 05/01 /08 04/30/08 04/29/08 04/28/08 04/27/08 04/26108 13 3/8" 20" Tubing Vol MUC2 TIO Report so 0 0 o Data Sheet 80 0 0 0 80 0 0 0 so 0 0 o MUC I-02 80 0 0 0 80 0 0 0 so 0 0 o INJECTION 80 0 0 0 80 0 0 0 90 0 0 o Permit # 1690670 100 0 0 0 100 0 0 0 100 0 0 o API # 50-733-20193-00 100 0 0 0 100 0 0 0 100 0 0 0 02/29/2008 to 05/31/2008 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 90 0 0 0 90 0 0 90 0 0 0 90 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 100 0 0 0 4/20/2009 3:14 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-05.x1s MUC I-02 Plot Pressure & Rate vs Time -Well MUC I-02 zoo zoo 180 180 ~9 5/8" 13 3/8" 160 ^ 160 20 Tubing Vol MUC2 140 140 120 120 d 7 N 100 ~ 1~ ~ ` a. a 80 - - 80 60 60 40 40 20 20 0 0 ~ r 0 0 O M ~ r r r r r 0 0 0 0 0 0 cp O~ N N W r r r ao o~ co co co w m m w co o~ eo 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 V I~ O N u7 ~ V i~ O M ~ m V w m m ro ro m m 0 0 0 0 0 0 o I~ O (7 O ~ N ~ ~ N N - m O aD N M O N •- ~ O O N N N N N N N ~ ~ ~ ~ ~ ~ N N M O O O N N N N O O N N N \ \ N N ~ ~ ~ O O O O O O O O O O O O O ~ ~ ~ N N N N N N N O O O O O O O N O Date 02/29/08 o2/2s/os 02/27/os o2/2s/os 02/25/08 02/24/08 02/23/08 02/22/os 02/21 /os 02/20/08 02/19/08 02/18/08 02/17/08 02/16/08 02/15/08 02/14/08 02/13/08 02/12/08 02/11 /08 02/10/08 02/09/08 02/08/08 02/07/08 02/06/08 02/05/08 02/04/08 02/03/08 02/02/08 02/01 /08 01 /31 /08 01 /30/08 01 /29/08 01 /28/08 01 /27/08 01/26/08 01 /25/08 20" Tu bing vol Mucz TIO Report 0 0 o Data Sheet 0 0 0 0 0 0 3 0 o MUC I-02 3 0 0 3 0 0 3 0 o INJECTION 3 0 0 3 0 0 3 0 o Permit # 1690670 2 0 0 2 0 0 0 0 o API # 50-733-20193-00 0 0 0 0 0 0 0 0 0 11130/2007 to 02/29/2008 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4/20/2009 3:13 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-02.x1s MUC I-02 Plot Pressure & Rate vs Time -Well MUC I-02 aoo 200 1ao 3s0 ~9 Sls" I ~ 13 3/8" ~ I 20" 160 -Tubing 300 `Vol MUC2 140 2s0 120 7 200 d 11~ N d ~ a ao 1so 60 100 - 40 50 20 0 0 r 0 r r r r r n 0 0 0 0 0 0 v r o M m m n r r~ n ~ n r~ ~ ~ ~ r n r r w w m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 c`v in m v r~ o n ~ m cu ~ ~ M ~ rn m w eo m w m m 0 0 0 0 0 0 0 N ~ e`o a r o O O O ~ ~ ~ ~ ~ ~ ~ _ N N N O O O N N N M O O O N (~ (~ (~ N (~ (~ (~ N N (~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O O O N N N fh O O O O O O O 13 318" 20" Tubina Vol MUC2 80 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 ao 0 0 0 so 0 0 0 ao 0 0 0 so 0 0 0 80 0 0 0 ao 0 0 0 ao 0 0 0 so 0 0 0 so 0 0 0 sa o 0 0 ~0 0 0 0 so 0 0 0 ao 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 ao 0 0 0 so 0 0 0 ao 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 so 0 0 0 ao 0 0 0 TIO Report Data Sheet MUC I-02 INJECTION Permit # 1690670 API # 50-733-20193-00 11 /01 /2007 to 01 /31 /2008 4/20/2009 3:12 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-01.x1s MUC I-02 i Plot Pressure & Rate vs Time - Well MUC I-02 aoo zoo ~9 5/8" 13 3/8" 180 350 20" Tubing Vol MUC2~ 160 300 - - -- -- - --- -- - - - - -- __ _- -- - 140 250 -- - - --- - -- 120 ~ ~ N 200 11~ ~ ` a. a 80 150 60 100 ., . . . 40 50 20 0 0 n 0 n n r n ~ ~ 0 0 o O o 0 ~ r~ ~ r ~ ~ ~ ~ ~ ~ ~ n n n ~ r r ~ r~ r ~ r ~ r 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O (") O~ O [7 cD O~ N ~ ~ O O O O O O O O O ~ ~ ~ .- ~ r .- V !~ O N N a0 V O (`') (O Q~ N ~ aD V I~ O ~ c0 O) N N N t+J O O O N N N N O O O N N N N O O O O ~ N N N N N N N N N N ~ r ~ ~ ~ ~ r ~ ~ r r r r ~ ~ ~ ~ r ~ ~ ~ ~ ~ r Date 12/31 /07 12/30/07 12/29/07 12/28/07 12/27/07 12/26/07 12/25/07 12/24/07 12/23/07 12/22/07 12/21/07 12/20/07 12/19/07 12!18/07 12/17/07 12/16/07 12/15/07 12/14/07 12!13/07 12/12/07 12/11/07 12/10/07 12/09/07 12/08/07 12/07/07 12/06/07 12/05/07 12/04/07 12/03/07 12/02/07 12/01/07 11 /30/07 11 /29/07 11 /28/07 11 /27!07 11 /26/07 13 318" 20" 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 70 80 4/20/2009 3:11 PM - TIO Reports 7e.xls TIO Report o i o o Data Sheet 0 0 0 0' 0 0 of o o MUC I-02 0; 0 0 Oi 0 0 o~ o o INJECTION 0 0 0 0~ 0 0 0 0 o Permit # 1690670 0 0 0 0 0 o API # 50-733-20193-00 0 0 0 0 0 0 0 0 0 09/30/2007 to 12/31 /2007 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0' 0 0 0' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2007-12.x1s MUC I-02 ,. zo° so so so so so so ao 90 90 90 90 90 90 90 90 85 85 85 85 85 so so so 85 85 85 85 85 85 85 85 85 85 85 85 90 12/31/2007 9:12 AM - TIO Reports 7e.xls TIO Report Data Sheet 0 0 ~ MUC I-02 0 0 0 o 0, e o` o o a:.., _. o INJECTION 0 0 : 0' 0 0' 0 ,~ 0 q, Permit # 1690670 0' 01 - 0 0 ~ o 0, ; . o o, , _ ~ API # 50-733-20193-00 o_ o ~: 0 o :; 0~ : , o o. ~ 01 /30/2007 to 04/30/2007 0 ', 0 o o ~'; 0, o 0 Oi 6 o ,~ o; a 0 , o', `, a o~ o q 0 0 0 0 0 0 0 0 _ 0 U 0` _; - o 0 0_' 0 0 0 "'o 0 0~ o 0 0 °o 0 :. 0, _ o 0 :: 0. o 0 0 0 0~ 0 0 0 0 0 J J Dolan CI_In~Rpt_GranitePt_Unocal_2007-04.x1s MUC I-02 Plot Pressure & Rate vs Time -Well MUC I-02 zoo ~ ,,, 9. o, ,,,., ,.u . ,,~ m,~ w, 200 180 180 L i 9 5/8" ~ 13 3/8" t 60 ~ 60 i ~ 20 Tubing Vol MUC2 140 - 140 120 -- - --._ - 120 3 ~ ~ 100 f id' ` ~ ! I E k E { 80 - - - ---- - _ ~=_ - 80 60 - - - 60 40 - - --- 40 20 - - - 20 0 0 O y I~ O M ~ O O ~ ~ ~ m N ~ m M t0 W (V N ~ Q 1~ O (O (O ~ N N N t7 O O O ` ~ ~ N N N t\ O O ~ (V N O ~ aD N N N (`O'1 O O O O O O O O O O O ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Date 13 318" 20" Tuhing V~11 MUC2 TIO Report 12/31 /06 80 0 0= Data Sheet 12/30/06 80 0 0. 0 12/29/06 90 0 0 0 12/28/06 90 0 0 ' 0 MUC I-02 12/27/os a5 0 0, o 12/26/06 85 0 01 0 12/25/06 90 0 0 INJECTION 1z/2a/os 90 0 0;:. o 12/23!06 80 0 0 0 12/22/06 80 0 0 0 Permit # 1690670 12/zoos 90 0 0 © 12/20/os ao 0 0 _ o 12/19/06 8U 0 0 ' ~i API # 50-733-20193-00 12n8/os ao 0 o-; ' ~ 12/17/os ao 0 0 ;o 12/1s/os ao 0 n ' o 10/01 /2006 to 12/31 /2006 12n 5/os so 0 0 v 12/14/06 90 0 0 0 12/13/06 90 0 0 _, r0 12/12/06 90 0 Oi 0 12/11/06 90 0 0 0 12/10/06 90 0 0 0 12/09/06 90 0 0 0 12/08/06 90 0 0 0 12!07/06 100 0 0 0 12/06/06 100 0 0 0 12/05/06 90 0 0 0 12/04/06 90 0 0 G 12/03/06 100 0 0 - 0 12/02/06 99 0 0 0 12/01 /O6 99 0 0 0 11 /30/06 99 0 J 0 11 /29/06 99 0 0 0 11 /28/06 99 0 0 0 11 /27/06 100 0 0 0 11 /26/06 90 0 0 0 12/31/2007 9:11 AM - TIO Reports 7e.xls J J Dolan CI_InLRpt_GranitePt_Unocal_2006-12.x1s MUC I-02 • • Pressure O ~ ~ ~ ~ O O O O O O O O O N O 9/02/06 i ~ 9/05/06 9/08/06 ~ I 9/11/06 ~ ~ o w ~ 9/14/06 ~ w c~ °D_ ~ 9!17/06 f 9/20/06 ~ 9/23/06 ' ' ~ ~ b ~ O 9/26/06 ~ '"~ 9/29/06 ;~ I ~ , 10/02/06 x ~' C 10/05/06 ~ `' 10/08/06 ~, s ~' /b 10/11/06 ~ y ' ~ 10/14/06 C 10/17/06 ~ , 10/20/06 ~.,. 10/23/06 ~D 10/26/06 ~ ~~ ~ ~'' CD 10!29/06 ~ ~ 11 /01 /06 11 /04/06 n ~--~ 11 /07/06 - O N 11/10/06 11/13/06 ' ~, 11/16/06 11/19/06 11 /22/06 11 /25/06 11 /28/06 i '~ 12/01 /06 ~ < ,. ~.: ~ ~. , .... ~~. , . ;p ~ - . , • • Pres sure O O O O O O N 0 0 0 0 ° O 10/03/08 10/06/08 10/09/08 10/12/08 10/15/08 10/18/08 10/21 !08 I I I 10/24/08 c o 10/27/08 ; o_ _ w ~ 10/30/08 ~ ~' ~^' ~ 11 /02/08 ~ _ 11 /05/08 _ _ _ 11 /08/08 11/11/08 11 /14/08 _ ~ 11 / 17/08 11 /20/08 C ~ 11 /23/08 ~ 11 /26/08 ,~ 11 /29/08 ~D 12/02/08 ~ ~ ~ 12/05/08 ~ 12/08/08 ~ 12/11 /08 ~ 12/14/08 12/17/08 12/20/08 12/23/08 ~ ,~ 12/26/08 I ~ 12/29/08 C 1 /01 /09 v' 1 /04/09 ~] 1 /07/09 ~~ 1 /10/09 1 /13/09 ~ 1 / 16/09 ~ 1 /19/09 1 /22/09 ;I rp 1 /25/09 '~ r~r 1 /28/09 1 /31 /09 2/03/09 2/06/09 (~ 2/09/09 i.,~ 2/12/09 ~ C 2/15/09 N 2/18/09. 2/21 /09 2/24/09 2/27/09 3/02/09 3/05/09 3/08/09 3/ 11 /09 3/14/09 3/17/0 3/20/09 9 3/23/09 i 3/26/09 3/29/09 4/01 /09 O N O A O O W O O R~ ~ E, N ~ A ~ O O p ~ O o o O o • ~ ~~ 0 J Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Thursday, July 12, 2012 3:07 PM Q'q ? To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Chet Starkel; Reid Edwards Subject: 2012 June's GPP 44 -11 Monitoring Report Attachments: Master Well List TIO Report 2012 06 30.xls Hi Jim & Guy, Here is June's GPP 44 -11 monthly pressure report based on DIO #10, Rule #4 requiring daily pressures be taken on three wells and reported monthly on the 10 -406 injection report. The infrequent summer usage of the GPP 44 -11 well continued last month (used onl y once). The well performed as expected. As you can tell by the pressure swings, the operators are attempting to return the GPP 31 -14RD2 well to production. It looks like they had the well going a couple of weeks during June and then it started u- tubing gas. They will continue to work with this well over the summer to see if it can be flowed more consistently. From the attached data, there isn't any indication that the infrequent batch injections into GPP 44 -11 have affected the pressures in either of the other two wells. Larry 1 P lot Pressure & Rate vs Time - Well GP 44 -1• - 1200 1 000 -- - — _ 1. -- --- -- . -- — - — -- ---------------- -..._. .__...-- - - - - -. _ 1000 •■■■••■•9 5/8" 13 3/8" : _ Tubing 800 �VO144 -11 G/ L 3 ll vi a I I I 600m ci 400 rA I • I A —, /.. 400 I 200 I .L — ----- --- --_._.._._..___--- --__. --- 200 N N N N N N o `m m m co mm r N N N N N N N N M V in CO n n n n n n Date 13 3/8" 20" Tubing Vol 111 TIO Report 06/30/12 400 5 200 06/29/12 400 5 200 0 Data Sheet 06/28/12 400 5 200 0 06/27/12 400 3 200 0 06/26/12 400 3 1040 471 GP 44 -11 06/25/12 400 5 180 0 06/24/12 400 3 180 0 06/23/12 400 3 180 0 INJECTION ✓ 06/22/12 400 3 180 0 06/21/12 400 3 180 0 06/20/12 400 3 180 0 Permit # 1670700 06/19/12 400 3 180 0 06/18/12 400 3 180 0 06/17/12 400 3 180 0 API # 50- 733 - 20059 -00 06/16/12 400 3 180 0 06/15/12 400 3 180 0 06/14/12 400 3 180 0 12/30/2011 to 06/30/2012 06/13/12 400 2 180 0 06/12/12 400 2 180 0 06/11/12 400 2 180 0 06/10/12 400 2 180 0 06/09/12 400 2 180 0 06/08/12 400 2 180 06/07/12 400 1 180 0 06/06/12 400 2 180 0 06/05/12 400 1 180 0 06/04/12 400 1 180 0 06/03/12 400 1 180 0 06/02/12 400 1 180 0 06/01/12 400 1 180 0 05/31/12 400 1 180 0 05/30/12 400 1 180 0 05/29/12 400 1 180 0 05/28/12 400 1 180 0 05/27/12 400 1 180 0 05/26/12 420 1 180 0 7/17/2012 3:23 PM - TIO Reports 7e.xls 11 Dolan Master Well List TIO Report 2012 06 30 GP 44 -11 PloT Pressure & Rate vs Time - Well GP 31 -14R 1200 - /• 1. i 1000 �9 5/8" — — 13 3/8" Tubing 800 W - E' _______Iv, 600 - - i J I i i I 200 -- - - - - -- - - ---- — - --- -- - - - -- 0 . _ ____ _ __ N N N N N N o m ao m ao co n co N N N N N N N CO n 0 , n CO Date 7" 133/8" 20" Tubing TIO Report 06/30/12 . 850 385 6 80 06/29/12 70 365 5 70 Data Sheet 06/28/12 1150 375 5 1150 06/27/12 701 375 4 80 06/26/12 115x.' 365 4 1150 GP 31 -14RD2 06/25/12 1151- 370 3 1150 06/24/12 115$ 375 0 1150 06/23/12 100' 390 0 100 GAS LIFT 06/22/12 1001 390 0 100 06/21/12 1148- 380 0 90 06/20/12 1151- 380 0 80 Permit # 1002660 06/19/12 991 385 0 120 06/18/12 99' 380 2 100 06/17/12 1001 380 3 100 Sundry # 398 -200 06/16/12 940 380 5 100 06/15/12 900 380 5 80 06/14/12 800 370 5 80 API # 50- 733 - 10061 -02 06/13/12 8r 360 5 80 06/12/12 70 360 5 70 06/11/12 80 355 6 80 12/30/2011 to 06/30/2012 06/10/12 505 365 6 70 06/09/12 70 360 6 70 06/08/12 80 355 6 80 06/07/12 75 355 6 75 06/06/12 81 355 6 80 06/05/12 80 355 6 80 06/04/12 8' 360 5 80 06/03/12 80 360 5 80 06/02/12 80 360 5 80 06/01/12 80 360 5 80 05/31/12 80 360 5 80 05/30/12 80 360 5 80 05/29/12 80 360 5 8 8M 05/28/12 81 360 6 05/27/12 <- 83 360 6 80 05/26/12 360 5 80 7/17/2012 3:23 PM - TIO Reports 7e.xls 11 Dolan Master Well List TIO Report 2012 06 30 GP 31 -14RD2 i' Pl ot Pressure & Rate vs Time - Well MUC I -0 200 - 200 180 — — - - --- - 180 .....95/8" 133/8" 160 ........*20" 160 Tubing ......VoI MUC2 140 • 140 120 - ` 120 E H N r 100 — --- 1012 v m a ` 80 -- 80 60 -- — - 60 40 40 20 — 20 0 4' - 0 _ N N N N N N 8 m co m m m n N N N N N N Date 13 3/8" 20" TIO Report 06/30/12 100 0 06/29/12 100 0 Data Sheet 06/28/12 100 0 06/27/12 100 0 06/26/12 100 0 MUC 1 -02 06/25/12 100 0 06/24/12 100 0 06/23/12 100 0 INJECTION ''''' 06/22/12 100 0 06/21/12 100 0 06/20/12 100 0 Permit # 1690670 06/19/12 100 0 06/18/12 100 0 06/17/12 100 0 API # 50- 733 - 20193 -00 06/16/12 100 0 06/15/12 100 0 06/14/12 100 0 12/30/2011 to 06/30/2012 06/13/12 100 0 06/12/12 100 0 06/11/12 100 0 06/10/12 100 0 06/09/12 100 0 06/08/12 100 0 06/07/12 100 0 06/06/12 100 0 06/05/12 100 0 06/04/12 100 0 06/03/12 100 0 06/02/12 100 0 06/01/12 100 0 05/31/12 100 0 05/30/12 100 0 05/29/12 100 0 05/28/12 100 0 05/27/12 100 0 05/26/12 100 0 7/17/2012 3:22 PM - TIO Reports 7e.xls .1.1 Dolan Master Well List TIO Report 2012 06 30 MUC 1 -02 • Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] � 7- i 61 Sent: Tuesday, February 07, 2012 4:05 PM f zr To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Chet Starkel; Chris Kanyer; Luke Saugier Subject: 2012 Januarys GPP 44 -11 Monitoring Report Attachments: Master Well List TIO Report 2012 01 31.xls Hi Jim & Guy, Here is January's GPP 44 -11 monthly pressure report based on DIO #10, Rule #4 requiring daily pressures be taken on three wells and reported monthly on the 10 -406 injection report. The GPP 44 -11 well remains in full wintertime operation with water disposal occurring every two or three days. The pressures are staying within expected ranges. ✓ Although there wasn't any action with the GPP 31 -14RD2 well this last month, they will be continuing with intermittent oil skimming operations as the water it makes during full time production cannot be consistently disposed of in GPP 44 -11 and cannot be sent to the beach as the GPTF outfall line is frozen again for the winter. The OA in the MUCI -2 well ticked up a bit this last month, but nothing that looks to be related to the disposal operations. From the attached data, there isn't any indication that the ongoing batch injections into GPP 44 -11 have affected the pressures in either of the other two wells. Larry • • jiZri,ut 20 lZ gp- Plot Pressure & Rate vs Time - Well GP 44 -11 (1 /6,76 70c1 1200 / - 1200 —9 5/8" 13 3/8" —20" - 1000 •TU bing __ -_ L._____... _ _._ __ -. __ _ -__ __ -_ 1000 Vol 800 800 3 1 v) :2, 600 - - — . I E 600= 1 400 1 .... j'l r 200 - — ------ - - - 200 _ 7 O m o 35 W r M h N N_ N N N F. o o O . • Jabs 2a1v Plot Pressure & Rate vs Time - Well MUC I -02 (P ( 6 7o6?o) 200 - 200 180 — - 180 —9 5/8" 13 3/8" 160 `.— r - 20" - -- - 160 •Tubing —Vol 140 — — — — 140 120 -- — 120 100 102 ` 80 - - 80 60 60 40 - 40 20 20 0 A O W O W a0 r M M N N N N N f CO C O 0 C O O n • • rJait.c4,d Zulz t Plot Pressure & Rate vs Time - Well GP 31 -14RD2 (Pi ico 0460 ) 1400 •9 5/8" 1200 13 3/8" ittges,.......11...19 •20" ■Tubing 1000 800 v z N 0 a 600 - It 400 � I 200 - ^ 0 + _ N _ O W W CD W h f7 M N N N N N aD W O O C O O Plot Pressure & Rate vs Time - Well GP 44-11 soo t zoo ~9 5/8" 13 3/8" 20" 1000 -Tubing 500 Vol 44-11 - 400 Soo d N 600 - m a~ ` a zoo aoo too zoo 0 0 0 ~ m m m~ m~ m m~~ m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~~~ m m~ 0 0 0 0 0 0 m m 0 0 O M t0 O) N N a0 V r O N in N V r O t+1 t0 O~ V r O M ~ O~ N ~ ~ ~ N N W N N M O O O ~ ~ N N N M O O O ~ ~ ~ N N N N O O N N N N N (V (~ N N N ~ ~ ~ ~ ~ N (~ r r .- ~ ~ r r .- ~ ~ O O O O O O O O O O O O O ~ N N N N N N O O O O O O N N O O 13 3/8" 20" T ubing Vo l 540 13 960 540 13 200 540 13 960 540 13 200 540 13 970 530 13 200 550 13 225 540 13 200 560 13 225 540 13 200 550 13 997 540 13 200 540 13 200 520 13 200 520 13 220 520 13 200 520 13 982 520 13 200 520 13 240 520 13 200 540 13 200 540 13 200 540 13 200 520 13 200 530 13 200 520 13 200 530 13 200 530 13 200 530 13 950 530 13 200 530 13 990 530 13 500 0 530 13 1000 413 530 13 200 0 540 13 980 523 540 13 200 0 TIO Report Data Sheet GP 44-11 INJECTION Permit # 1670700 API # 50-733-20059-00 11/30/2008 to 02/2812009 4/20/2009 3:16 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2009-02.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 1200 600 ~9 5/8" 1i 500 1000 13 3/g~~ 20" Tubing -Vol 44-11 400 800 N 600 - - ~ d a 200 400 100 200 0 0 o~ oo ro ro m m m ro w w w m m m ao ro m m w ro m m m rn rn rn m rn m rn m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O > M cp T N ~ W V n o M (O Orn N in W V r o N ~ W V n o M <D M O O O N N N M O O O_ ~- ~ ~ N N N M O O O _ _ N N N N O ~ ~ ~ ~ ~ N ~ r ~ ~ ~ r ~ r r ~ ~ '- ~ ~ ~ r ~ O O O O O O O O O O Date 13 3/8" 20" Tubing Vol 44-11 TIO Report 01 /31 /09 530 13 200 507 Data Sheet 01/30/09 530 13 200 o 01/29~0~~ 180 530 13 200 477 01/28IC9 250 530 13 500 0 01/27%09 230 530 13 200 413 GP 44-11 01/26/09 230 530 13 200 0 01/25/09 200 540 13 200 523 ov2a/o9 210 Sao 13 200 o INJECTION 01/23/09 195 540 13 200 550 01/22109 195 540 13 200 495 01/21/09 . 250 540 13 200 o Permit # 1670700 01/20/09 ' 250 540 13 200 0 01/19/09 200 520 13 200 0 01/18/09 200 520 13 200 o API # 50-733-20059-00 01/17/09 : 75 520 13 200 371 01/16/09 250 520 13 200 0 01/15/09 260 520 13 200 0 10131/2008 to 01/31/2009 01/14/09 120 560 13 300 443 01/13/09 ` 180 520 13 200 412 01/12/09 . 225 520 13 200 0 01/11/09 ~ 250 520 13 200 276 01/10/09 < 250 520 13 200 0 01/09/09 ' 250 520 13 200 430 01/08/09 9 ~ 250 520 13 200 0 01/07/0 250 520 13 200 475 01/06/09 1: 250 520 13 200 0 01/05/09 :] 250 520 13 200 368 01/04/09 °. 250 520 13 200 0 01/03/09 250 520 13 200 399 01/02/09 ` 250 520 13 200 0 01/01/09 1 180 520 13 200 391 12/31/08 270 520 13 210 0 12/30/08 ! 180 520 13 210 247 12/29/08 315 520 13 200 0 12/28/08 ~ 315 520 13 200 0 12/27/08 ~, 315 520 13 200 0 4/20/2009 3:16 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2009-01.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 /zoo ~..,.,ri..~_.,_b~. ~.~ ,.,..,.~,.._.. _7.-,....w.~...,.._-...~....,~.__..-.~....b,,,.,.a_,_._m..~.~..._....~.,..~._..®.._...~.~_ soo ~9 5/8" t000 13 3/8" 500 20" Tubing -Vol 44-11 800 400 d 7 d w 600 -- - _ _ - - -- 3~ m ~ a 40o zoo zoo 100 0 0 O O O O O o 0 0 0 0 0 o O O o o O O O O o 0 0 0 0 o O o o O o V r O fh tD O> N N aD ~ lr1 <O m N N o0 ~ V r O M ~D O~ N ~ aD ~ V n O O O O ~ ~ ~ ~ N N N M O O O N N N t? O O O ~ ~ ~ N N N M O O O O O O O O O O O ~ ~ \ N N (~ N N N N N N N Date 9 518" 13 318" 20" Tubing Vol 44-11 12/31 /08 270 520 13 210 0 12/30/08 180 520 13 210 247 12/29/08 315 520 13 200 0 12/28108 315 520 13 200 0 12/27168 315 520 13 200 0 12/26/08 315 520 13 200 0 12/25/08 310 520 13 200 0 12/24/08 310 520 13 200 0 12/23/O~i 310 520 13 200 0 12/22/08 310 520 13 200 0 12/21/08 310 520 13 200 0 12/20/08 300 520 13 200 0 12/19/08 300 520 13 200 0 12/18!08 300 520 13 200 G 12/17/08 290 520 13 200 0 12/16/08 285 520 13 200 0 12/15105 270 520 13 225 0 12/14/65 240 520 13 225 0 12/13/0: 140 520 13 230 0 12/12/08 0 520 13 1000 346 12/11/05 320 540 13 200 0 12/10/08 320 540 13 200 0 12/09/0& 320 520 13 200 0 12/08/00 320 520 13 200 0 12/07/08 320 520 13 200 0 12!06/05 320 520 13 200 0 12/05/08 320 520 13 200 0 12/04108 320 520 13 200 0 12/03/08 320 520 13 200 0 12/02/05 320 520 13 200 0 12/01/08 320 520 13 200 0 11/30/08 320 520 13 200 0 11/29/68 320 520 13 200 0 11/28/08 320 520 13 200 0 11/27/08 320 520 13 200 0 11/26/05 320 520 13 200 0 4/20/2009 3:16 PM - TIO Reports 7e.xls J J Dolan TIO Report Data Sheet GP 44-11 INJECTION Permit # 1670700 API # 50-733-20059-00 10/01 /2008 to 12/31 /2008 CI_Inj_Rpt_GranitePt_Unocal_2008-12.x1s GP 44-11 r1 Plot Pressure & Rate vs Time -Well GP 44-11 600 400 350 ~9 5/8" 500 13 3/8" 20" ~ Tubing 300 Vol 44-11 400 250 ~ N 300 -- d ~ d ` a 150 200 100 100 50 0 0 ro 0 w m m m w 0 0 0 0 0 eo co m m ao ro m oo ~ co m o0 0~ m oo m m ao ao ao m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a r O N ~ N i m oo co m 0 0 0 0 O M [O O> t\ c0 O M tp ~ (_~ N O O O T ~ ~ ~ O~ O O O O O ~ ~ n V t~ a0 ~ a f` O M O m N N N th O O O ~ ~ •- N N N lh O O O m Q> O> O) Q~ O O O O O O O O O O \ O O O O O ~ ~ ~- ~ ~ ~ ~- ~ ~ `- ~ ~ ~ ~ `- ~ N N N N ~ `- ~ ~ Date 11 /30/08 11 /29/08 11 /28/08 11/27/08 11 /26/08 11 /25/08 11 /24/08 11 /23/08 11/22/08 11/21/08 11 /20/08 11/19/08 11/18/08 11/17/08 11/16/08 11/15/08 11/14/08 11 /13/08 11/12/08 11/11/08 11/10/08 11 /09/08 11 /08/08 11 /07/08 11 /06/08 11 /05/08 11104/08 11 /03/08 11 /02/08 11 /01 /08 10/31 /08 10/30/08 10/29/08 10/28/08 10/27/08 10/26/08 13 3/8" 20" Tu bing 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 510 13 200 520 13 200 540 13 200 540 13 200 540 13 200 540 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 520 13 200 540 13 200 540 13 200 540 13 200 540 13 200 540 13 200 540 13 200 540 13 200 530 13 200 voia4_t1 TIO Report 0 o Data Sheet 0 0 o GP 44-11 0 0 o INJECTION 0 0 o Permit # 1670700 0 0 p API # 50-733-20059-00 0 0 0 08/31 /2008 to 11 /30/2008 0 0 0 0 0 0 0 0 0 0 0 0 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-11.x1s GP 44-11 4/20/2009 3:16 PM - TIO Reports 7e.xls Plot Pressure & Rate vs Time -Well GP 44-11 800 400 ~9 /5 8 ~ 13 3/8" 700 20° 350 ~ Tubing Vo 144-11 600 300 500 250 w 400 2~ d --- a. a 300 150 200 100 100 50 0 0 0 0 7 0 0 0 0 0 0 ~ m N N a 0 O o O o 0 0 0 0 0 0 0 0 0 0 0 0 t` O N N O r O M ~ ~ N in a0 O 0 0 0 0 0 0 0 0 V r O M iD O~ M r= 0 c O w 0 _0 O O N w co co ao a`o ao 0 0 0 0 0 0 N w 0 a _ N t~ O O O N N N N O O O oo m rn rn rn m rn rn rn rn rn rn o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ~ ~ N N N N O 0 0 0 0 0 0 0 ~ ~ ~- Date 9 5/8" 13 318" 20" Tubing Vo l 44-11 TIO Report 11/01/08 320 540 13 200 0 10/31108 320 540 13 200 0 ~8t8 Sheet 10/30/08 315 540 13 200 0 10/29//18 315 540 13 200 0 10/28/08 315 540 13 200 0 GP 44-11 10/27/08 315 540 13 200 0 10/26!0~~ 320 530 13 200 0 10/2510:? 310 540 13 200 0 INJECTION 1012410" 310 540 13 200 0 10/23!08 310 530 13 200 0 10/22!Oi~ 310 530 13 210 0 P@fRllt # 1670700 10/2108 310 540 13 200 0 10/20/08 235 510 13 210 0 10/19/08 235 510 13 210 o API # 50-733-20059-00 10/18/08 235 510 13 210 0 10/17/08 235 510 13 210 0 10/16/0--s 235 510 13 210 0 07/31/2008 to 11/01/2008 10/15/03 300 550 13 220 0 10/14/08 300 550 13 220 0 10/13/08 300 550 13 220 260 10/12i0f~ 300 550 13 225 0 10/11i0~' 275 540 13 220 0 10/10!08 275 540 13 220 0 10/09/08 325 540 13 0 1010810; 325 540 13 200 208 10/07/OS 325 540 13 200 0 10/06/G8 320 540 13 200 0 10/05/08 320 540 13 200 0 10/04/08 320 540 13 200 0 10/03/08 320 540 13 200 0 10/0210£s 320 540 13 200 0 10/01 i~'~8 320 540 13 200 0 09/30/C8 320 540 13 200 0 09/29/05 320 540 13 200 0 09/28/OF, 320 540 13 200 0 09/27/uF. 320 540 13 200 G 4/20/2009 3:15 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-10.x1s GP 44-11 i Plot Pressure & Rate vs Time -Well GP 44-11 800 200 -9 5/8" X00 13 3/8" 180 20" Tubing Vol 44-11 160 600 140 500 120 ~ 400 d 1 N ~ d a ~. so 300 ~ -- - - -- 60 200 40 100 20 0 p m m m o~ m 0 O c") O m o~ m m 0 0 0 0 ch t0 ~ N O O O r O O O O m m m w o~ ro w w w co m m m m oo ro w m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ap 7 f~ O N N W V 1~ O M O m V ~ ~ N N N M O O O ~ ~ ~- N N N N O O O O O O O O O O O O O O O O O O O O m m m m 0 0 0 0 0 0 r O (`~ O O> N O ~ ~ ~ ~ N O O O O O O 0 in N O 0 ~ N O Date 9 5/8" 13 3/8" 20" Tubing Vol 44-11 09130/08 320 540 13 200 0 09129/08 320 540 13 200 0 09/28108 320 540 13 200 0 09/27/08 320 540 13 200 0 09/26/08 320 540 13 200 0 09/25/08 320 540 13 200 0 09/24/08 315 540 13 200 0 09/23/G8 315 540 13 200 0 09/22108 310 540 13 200 0 09/21108 260 540 13 210 0 09/20/0& 320 540 13 220 0 09/19/08 320 540 13 220 0 09/18/08 320 560 13 200 111 09/17/08 320 560 13 200 0 09/16/08 320 560 13 200 0 09/15/08 320 560 13 200 0 09/14/08 320 560 13 200 0 09/13/08 320 560 13 200 0 09/12/08 300 560 13 200 0 09/11x08 290 560 13 200 0 09110!08 220 560 13 200 87 09/09/08 330 560 13 200 0 09/08~Oc 330 560 13 200 0 09/07%08 330 560 13 200 0 09/0610~~ 330 560 13 200 0 09/05'08 330 560 13 200 0 09/04x08 560 13 200 0 09/0308 330 560 13 200 0 09/02x08 330 560 13 200 0 09/01?OP, 330 560 13 200 0 08/31~OS 330 560 13 200 0 08/30lOS 330 560 13 200 0 08/29/08 330 560 13 200 0 08/28/08: 330 560 13 200 0 08/27/08 330 560 13 200 0 08/26/08 330 560 13 200 0 TIO Report Data Sheet GP 44-11 INJECTION Permit # 1670700 API # 50-733-20059-00 06/30/2008 to 09/30/2008 4/20/2009 3:15 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-09.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-ll /zoo aoo ~9 5/8" 13 3/8" 350 1000 20" -Tubing -Vol 44- J 300 800 250 N 600 d a 1so 400 100 200 50 0 0 co w m m m co o~ m oo w m ro m m ~ o~ eo 0 0 r~ M O ~n io 0 0 w w co m m m oo 0 0 0 0 0 0 0 co rn N in w ~ O O ~ ~ ~ N N co co co ~ co ~ ~ 0 0 0 0 0 0 0 w m ao o~ o~ ao w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ o M ~ rn N ~ co v ~ O c~ in m v r o r~ N M O O O ~ ~ ~ N N N (h O O O ~ ~ ~ N N ~ ~ ~ r n r` ~ r r n r n ao w co m m w m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~o rn N N ro w 0 0 Date 9 5/8" 13 3/8" 20" Tubing Vof 4 4-11 08/31/08 330 560 13 200 0 08/30/08 330 560 13 200 0 08/29ID8 330 560 13 200 0 08/28/0& 330 560 13 200 0 08/27!OS 330 560 13 200 0 08/26108 330 560 13 200 0 08/25/08 320 550 13 200 0 08/24%08 320 550 13 200 0 08/23/68 320 550 13 200 0 08/22108 320 550 13 200 0 08/21/08 320 550 13 200 0 08/20108 320 550 13 200 0 08/19/08 320 550 13 200 0 08/18!08 320 550 13 200 0 08/17/08 330 550 13 225 0 08/16; G8 330 550 13 225 0 08/15/08 ` 330 550 13 225 0 08/14/08 ' 330 550 13 225 158 08/13/08: 375 560 13 175 0 08/12/08 ' 375 560 13 175 0 08/11/08 ` 375 560 13 175 0 08/10/08 ' 375 560 13 175 0 08/09/08 ' 370 560 13 175 0 08/08/08 '' 360 560 13 190 0 08/07/08' 360 560 13 190 0 08/06/08' 360 560 13 190 0 08/05/08 i 345 560 13 190 0 08/04/08 w 345 560 13 190 0 08/03/08 ' 335 560 13 190 0 08/02/08 ~ 320 560 13 190 0 08/01 /08 !~ 260 560 13 190 0 07/31/08 ~: 65 560 13 700 66 07/30/08 { 315 560 13 200 0 07/29/08~~ 310 560 13 200 0 07/28/08 ` 305 560 13 200 0 07/27/08'. 300 560 13 200 0 4/20/2009 3:15 PM - TIO Reports 7e.xls J J Dolan TIO Report Data Sheet GP 44-11 INJECTION Permit # 1670700 API # 50-733-20059-00 05/31/2008 to 08/31/2008 CI_Inj_Rpt_GranitePt_Unocal_2008-08.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 1 zoo soo ~9 5l8" 13 3/8" 20" 1000 -Tubing 500 -Vol 44-11 800 400 d ~ N 600 d d a aoo zoo zoo 100 0 0 0 0 o O O o 0 0 0 0 0 0 0 0 0 0 o O o 0 0 0 0 0 0 0 0 0 0 0 0 o " ~ co m o ~ m rn A ~n w c~ ~ ~ v n o c~ ~ co a ~ N N N N N O O O h a r o ~ ~ ~ N <n N co m N N ( ) v 0 O O O ir> u> v> 0 0 0 _ _ _ N N ( O O O in ~n v> ~n u> in ~n ~ co in ~ ~ <o o <o ~ ~ n n n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ~ `r n 0 0 0 0 r= 0 n n 0 0 Date ~ 13 318" 20" Tubing Vol 44-11 TIO Report 07/31108 65 560 13 700 66 07/30i0~, 315 560 13 200 0 ~8t8 Sheet 07129108 310 560 13 200 0 07/28/08 305 560 13 200 0 o7/27io~~ 300 5so 13 200 o GP 44-11 07/26/08 275 560 13 200 0 07/25102 200 560 13 225 84 o7/2a;o2 320 5so 13 180 o INJECTION 07/23/08 ~ 320 560 13 180 0 07/22/08 320 560 13 180 0 07/21/08 320 560 13 180 o Permit # 1670700 07/20/08. 320 560 13 180 0 07/19/08 320 560 13 180 0 o7n 8/os '' 320 5so 13 190 o API # 50-733-20059-00 07/17/08 ' 320 560 13 190 0 07/16/08 320 560 13 180 0 07/15/08 320 560 13 180 0 04/30/2008 to 07/31/2008 07/14/08 320 560 13 190 0 07/13/08 320 560 13 175 0 07/12/08 'i 320 560 13 175 0 07/11/08 320 560 13 175 0 07/10/08 ~'i 320 560 13 175 0 07/09/08 ~ 320 560 13 175 0 07/08/08 320 560 13 200 0 07/07/08 i 320 560 13 200 0 07/06/08 ' 320 550 13 190 0 07/05/08 ' 315 560 13 190 0 07/04/08 ' 315 560 13 190 0 07/03/08 315 13 190 0 07/02/08 ~ 315 560 13 190 0 07/01/08 ' 315 560 13 190 0 06/30/08 h 310 560 13 180 0 06/29/08 ' 310 560 13 180 0 06/28/08 310 560 13 170 0 06/27/08 310 560 13 170 0 06/26/08 310 560 13 175 0 4/20/2009 3:14 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-07.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 /zoo looo ~9 5/8" 13 3/8" 900 20" 1000 Tubing Vol 44-1 P. 800 700 800 --- 600 600 50 N - ~ d ` a 400 400 300 200 200 100 0 0 m m m m m 0 0 0 0 0 co m co m m m w m m m m ao ro w m m m ro w w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m w o~ o~ m o~ 0 0 0 0 0 0 Ih fp W N M O O O M 7 a ~ V O O O O O ~ ep a r O M O O~ N ~ W ~ V I~ O N N W _ N N N M O O O N N N M O O O V V V a a V N ~ N N N ilJ ~ in N to (O <D O t0 ( O O O O O O O O O O O O O O O O O O O O V r O M O m ~ N N N N O tD <O tp cD c0 O O O O O O Date 9 518" 13 3/8" 20" Tubing Vol 44-11 TIO Report 06/30%O8 310 560 13 180 0 06/29/08 310 560 13 180 0 data Sheet 06/28/08 310 560 13 170 0 06/27/08 310 560 13 170 0 06/26/0E 310 560 13 175 o GP 44-11 06/25,'08 310 550 13 160 0 06/24/08 300 560 13 190 0 os/231o8 300 560 13 200 o INJECTION 06/22iG8 300 560 13 200 0 06/21'08 300 560 13 200 0 06/20IG8 300 560 13 220 0 P@i'llllt # 1670700 06/191OF 300 560 13 200 0 06/18'00 300 560 13 200 0 os/17~os 300 560 13 200 n API # 50-733-20059-00 06/16/08 300 560 13 200 0 06/15/08 300 560 13 200 0 06/14!:"?8 300 560 13 200 0 03/31/2008 to 06/30/2008 06/13/0° 300 560 13 200 0 06/12/G8 290 560 13 200 0 06/11IU8 290 560 13 200 0 06/10/C~~ 290 560 13 200 0 06/09;08 290 560 13 200 0 06/08/08 290 560 13 190 0 06/07/08 285 560 13 190 0 06/06 08 280 560 13 200 0 06/OS'7~c 260 560 13 200 0 06/04%08 220 560 13 200 0 06/03,!1 F: 50 560 13 1000 318 06/02/05 300 560 13 190 0 06101 ~ OS 290 560 13 200 0 05/31 ~ C n 260 560 13 210 0 05/30!GS 260 560 13 210 0 05/29/08 260 560 13 210 0 05/28/0€~ 260 560 13 210 0 05/27/08 260 560 12 210 0 05/26/08 260 560 13 210 0 4/20/2009 3:14 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-06.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 1200 looo ~9 5/8" 13 3/8" 900 20" 1000 -Tubing Vol 44-11 800 700 800 600 a m ~ 600 - 501 d ~ a 400 400 300 200 200 100 0 0 m m m m ro ro m ro ro w o m m m m m m m ro m m m m o~ m o ro w w ro m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O~ M cp ~ N N ~ V I~ O N ~ ~ O I~ O M (O 01 N N W ~ r O M cp ~ N O O O N N N t7 O O O N N N N O O O N N N N N f7 M M M M M M M M M O V 7 V V V a 7 O 7 N N N N to N ~ N ~ N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O Date 9 5/8" 13 3/8" 20" Tubing Vol 44-11 TIO Report 05/31/G8 260 560 13 210 0 05/30/08 260 560 13 210 0 ~8t8 Sheet 05/29/08 260 560 13 210 0 05/28%(i~ 260 560 13 210 0 05/27I0< 260 560 12 210 0 GP 44-11 05/26/C~fl 260 560 13 210 0 05/2510r 260 580 13 210 423 o5/2a;o8 290 5so 13 200 o INJECTION 05/23/08 290 560 13 200 0 05/22/0, 285 560 13 200 0 05/21/08 280 560 13 200 0 Pel'illlt # 1670700 05/20; 0-°~ 280 580 13 200 0 05/19/0£1 260 600 13 250 448 05/18 Oc; 280 580 13 225 o API # 50-733-20059-00 05/1710e 260 600 13 275 532 05/16/0: 270 580 13 225 0 05/15!Gr, 245 600 13 250 529 02/29/2008 to 05/31/2008 05/14/08 280 580 13 200 0 05/13/')8 260 600 13 250 480 05/12iG~s? 280 580 13 200 0 05/11/08 280 595 13 220 502 05/10/08 275 580 13 200 0 05/09i!'a 260 590 13 220 493 05/08/0„ 280 580 13 200 0 05/07/08 280 590 13 200 498 05/06/U& 270 580 13 200 0 05/0510(3 260 580 13 225 424 05/04/C8 260 580 13 225 05/03/08 220 600 13 300 541 05/02/08 270 570 13 225 0 05/01 /OS 250 600 13 250 474 04/30.08 260 570 13 250 0 04/29-0c 240 600 13 250 541 04/28!Oc~ 250 570 13 200 0 04/27/08 220 580 13 225 506 04/26/08 250 580 13 240 0 4/20/200 9 3:13 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-05.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 600 600 ~9 /5 8 00 500 5 13 3/8" 20" Tubing Vol 44-11 400 400 -- d 3 N y 300 a 200 200 100 100 0 0 m m m m ro ~ 0 0 O M n r~ ~ ~ 0 0 0 0 ~O ~ N ~ r r~ ~ r n w m ro ro w m oo m m ao m ro w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ V !~ O N N W V I~ O M iD O~ V I~ o~ w 0 0 0 0 O M c0 m 0 0 N N 0 W N M O N O O ~ ~-- N (V N N r N N N ch O O O N N N N O O O N N N N N ~ ~ ~ N N N ~ O O O O O O O O O O O O O ~ ~ ~ ~ N N N N O O O O N N N N O O N O Date 02/29/08 02/28/oa 02/27/08 02/26/08 02/25108 02/24/08 02/23/08 02/22/08 02/21 /08 02/20/08 02/19/08 02/18/08 02/ 17/08 02116/08 02/15/08 02/14/08 02/13/08 02/12/08 02/11 /08 02/10/08 02/09/08 02/08/08 02/07/08 02/06/08 02/05/08 02/04/08 02/03/08 02/02/08 02101 /08 01 /31 /08 01 /30/08 01 /29/08 01 /28/08 01 /27/08 01 /26/08 01 /25/08 13 3/8" 20" Tubing Vol 44-11 560 13 235 580 13 235 560 13 235 560 13 235 580 13 245 580 13 245 560 13 225 560 13 250 560 13 225 560 13 540 560 13 245 560 13 250 560 13 200 560 13 200 550 13 200 540 13 210 540 13 200 540 13 200 550 13 200 550 13 250 5 560 13 250 560 13 250 4 560 13 250 560 13 250 534 550 13 225 0 550 13 225 498 540 13 200 0 540 13 200 531 540 13 200 0 540 13 210 457 540 13 200 0 540 13 200 507 530 13 190 0 530 13 210 505 530 530 13 13 200 190 0 484 TIO Report Data Sheet GP 44-11 INJECTION Permit # 1670700 API # 50-733-20059-00 11/30/2007 to 02/29/2008 4/20/2009 3:13 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-02.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 soo sooo 4500 00 ~9 5/8" 5 13 3/8" a000 20" Tubing -Vol 44-11 3500 400 3000 ~ 300 a~ 2 N ~ d a zooo zoo lsoo sooo 100 soo 0 0 ~ t~ ~ ~ n r ~ r r r r r r r- r n n ~ r~ r ~ m m m o~ co o~ m ro ro m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O ~ N ~ W ~ M cD Q> N N eD V I~ O V 1~ O M ~ O> N N a0 V O N t _ O O O N N N O O O ~ r- ~ N N N N O O O N N N M a ~ a a r r r r .- .- ~ r ~ O O O O O O O O O O Date 9 5(8" 13 318" 20" Tubing Vol 44-11 TIO Report 01/31;05 150 540 13 210 457 01/30!08 210 540 13 200 0 ~8t8 Sheet 01/29,08 130 540 13 200 507 01/28!08 160 530 13 190 0 01/27/08 160 530 13 210 505 GP 44-11 01/2608 160 530 13 200 0 01/25%08 160 530 13 190 484 01124!08 120 530 13 190 0 INJECTION 01/23,0& 120 530 13 190 465 01/22/08 120 530 13 190 0 01/21/GP~ 120 560 13 180 540 P@ffillt# 1670700 01/20/08 120 560 13 180 484 01/19/08 120 560 13 180 0 ov18/o5 120 5so 13 20o s73 API # 50-733-20059-00 01/17/02 0 540 13 200 0 01/16/(18 110 520 13 200 598 01/15 ~~.° 28o s2o 13 150 0 11/01/2007 to 01/31/2008 01/14/CJ 280 540 13 150 0 01/13/02 280 540 13 110 0 01/12/08 280 540 13 110 0 01/11!08 280 540 13 180 0 01/10/08 280 540 13 180 0 01/09 Q!' 280 540 13 180 0 01/08/i~8 280 540 13 175 0 01/07/08 280 540 13 175 0 01/06/05 280 540 13 160 0 01/05/Oc 280 540 13 160 0 01/04105 280 540 13 160 0 01/03108 280 540 13 160 0 01/02/0° 280 540 13 160 0 01/01/08 280 540 13 160 0 12/31IC~/ 280 540 13 160 0 12/30!0 / 280 540 13 160 0 12/29r(~r 260 540 13 160 0 12/28107. 260 540 13 160 0 12/27/07 ~ 260 540 13 160 __ _ _ Q 4/20/2009 3:12 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2008-01.x1s GP 44-11 r i Plot Pressure & Rate vs Time -Well GP 44-11 800 taoo 9 5/8" 13 3/8" 700 - 20" Tubing 1200 Vol 44-11 600 1000 500 - --- 800 3 N 400 y _ _ - - ~ d a sao 300 - -- ---- 400 200 100 200 ~ 0 O r ~ ~ n 0 O (") ~ n n r 0 0 0 0 (~1 t0 O~ N O O O ~ n n n r r~ ~ r ~ ~ ~ ~ ~ ~ ~ n r ~ ~ n n r n r~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N o0 O 1~ O N N ~ V h O t`') iD O~ (~ N W ~ V ~ O M <D O~ N N N N O O O ~ ~ ~ N N N N .- r N N N t7 O O O ~ O O O O O r .- .- r _ O O O O O O ~ N N N N N N N N N (~ r r ~ r ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ r .- .- ~ ~ ~ r ~ ~ ~ r Date 12/31 /07 12/30/07 12/29/07 12/28/07 12/27/07 12/26/07 12/25/07 12/24/07 12/23/07 12/22/07 12/21 /07 12/20/07 12/19/07 12/18/07 12/17/07 12/16/07 12/1 s/o7 12/14/07 12/ 13/07 12112/07 12/11/07 12/10/07 12/09/07 12/08/07 12/07/07 12/06/07 12/05/07 12/04/07 12/03/07 12/02/07 12/01 /07 11 /30/07 11 /29/07 11 /28/07 11 /27/07 11 /26/07 13 318" 20" Tubing Vol 44-11 540 13 160 0 540 13 160 0 540 13 160 0 540 13 160 0 540 13 160 0 540 13 160 0 540 13 160 0 540 3 160 0 540 12 160 0 540 12 160 0 540 12 160 0 540 12 160 0 540 12 160 0 540 12 160 0 540 12 160 0 540 11 160 0 540 12 160 0 540 12 160 0 540 12 160 0 540 12 160 0 540 13 160 0 540 13 165 0 540 13 165 0 540 13 155 0 540 13 155 0 540 13 155 0 540 13 155 0 540 13 155 0 540 13 145 0 540 13 145 0 540 13 145 0 540 13 145 0 540 13 145 0 540 13 145 0 540 13 190 0 540 13 145 0 TIO Report Data Sheet GP 44-11 INJECTION Permit # 1670700 API # 50-733-20059-00 09/30/2007 to 12/31/2007 4/20/2009 3:11 PM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2007-12.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 soo ; ~ laoo -s s/s° 13 3/8" j 20„ X00 ~ Tubing 1200 ~Vo144-11 6 600 - __ _ _ _ 1000 500 800 d ~ N 400 ~ i d a ~ : soo 300 1 P k 4 400 200 ?00 100 0 r t~ ~ n ~ n ~ n n ~ n n r n r n ~ r~ ~ r r~ n n n ~ n n ~ r ~ ~ O O O o o O O O O O o O O O O O O O O O O O O_ O O O O O O o O f~ O ~ f0 T N ~ OD tD Of N N aD Q I~ O c1 O~i N ~ m Q 1~ O O ~ O ~ ~ ~ ~ N N ` (+I O O O ~ ~ ~ N N N t7 O O O ~ ~ ~ N N N M pp m m a0 ~ ~ pp ap ~ m m m m W ~ pf m ~ m W 01 O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O Date 13 3/8" 20" Tubing Vol 4a-11 TIO Report 10/31/07 560 13 165. ~ Data Sheet 10/30/07 560 13 165 0 10/29/07 560 13 165 0 10/28/07 560 13 165 > 0 10/27/07 560 13 165'. . 0 GP 44-11 10/26/07 560 13 165' ?73 10/25/07 560 13 165'r o 1o/2aro7 580 13 165' 632 INJECTION 10/23/07 600 13 165' 1359 10/22/07 600 13 16.5 i 35 10/21!07 599 13 i68 71i; Permit# 1670700 10/20/07 599 13 168 0' 10/19/07 600 13 I95 488 10/1 s/o7 585 13 165- o API # 50-733-20059-00 10/17/07 600 13 195 450 10/16/07 590 13 170 0 1a15/o7 600 13 220 5a1 08/01/2007 to 10/31/2007 10/14/07 560 13 165' 6 10/13/07 580 13 200- 483 10/12/07 560 13 165'.. 0 10/11/07 570 13 1 T5! 379' 10/10/07 560 13 160'.. 0 10/09/07 560 13 170' 331. 10/08/07 560 13 170 0 10/07/07 560 13 170 0 10/06/07 560 13 185 184 10/05/07 560 13 150. o 10/04/07 560 13 150 0 10/03/07 560 13 150 0 10/02/07 580 13 154 0 10/01 /07 580 13 155 0 09/30/07 560 13 150 0 09/29/07 560 13 150 0 09/28/07 560 I3 155 0 09/27/07 560 13 160 0 09/26/07 560 13 160 0 12/31/2007 9:13 AM - TIO Reports 7e.xls J J Dolan CI_InLRpt_GranitePt_Unocal_2007-10.x1s GP 44-11 800 700 600 500 7 H 400 a 300 200 ioo 600 500 400 m d' zoo ioo o n n 0 0 a O O ~^ ~ ~~ n n n n n 0 0 0 0 0 n o io so rn O .- ~- ~ ~ ~ r r r J O O O n 0 N N n O n 0 .n N O n n n 0 0 0 ao ch N c` O n c0 O O O n n 0 0 m O O a0 aD o O n n n n n n n n n n 0 0 0 0 0 0 0 0 0 0 N ~ ~ o ~ o N u~ ~ ~ ~ N N N tD O O O m ap ~ m aD aD aD m Ql W O O O O O O O O O n n n n n n n 0 0 0 0 0 0 0 ~ o n o cn o rn ~ ~ ` N N N OI D7 W Of rn m OI O O O O O O O Date ~ 5Ig"` 13 3/8" 20" Tubing ~ Vol as-11 TIO Report 09/30 ?'(~i 560 13 15U 0 Data Sheet 09/29 _ -, 2;~~7 560 13 150; 0 09/28/07 ~ 560 13 1551 0 09/27/07 560 13 160 0 GP 44-11 09/26/07 560 13 160 0 09/25/07 560 13 162 0 09/24/07 560 13 185 0 INJECTION os/z3/o7 5so 13 1ao 218 09/22/07 580 13 160 0 09/21 i07 580 13 160 ~ 0 Permit # 1670700 09/20/07 580 13 160 0 09/19/07 580 13 160 0 09!18/07 580 13 1651 0 API # 50-733-20059-00 osn7ro7 5so 1s5 o 09/16/07 580 13 170 0 09/15/07 09/14/07 580 580 13 13 180 160 106 0 07/01/2007 to 09/30/2007 09/13/07 580 13 160 0 09/12/07 580 13 160 0 09/11 /07 580 13 165 A 09/10/07 570 13 170 0 09/09/07 560 13 150 169 09/08/07 580 13 150 0 09/07/07 580 13 150 n 09/06/07 580 13 150 0 09/05!07 58U 13 150 1 0 09/04/07 580 13 150 0 09/03/07 580 13 150 0 09/02/07 580 13 150 0 09/01/07 580 13 150 0 08/31 /07 600 12 160 0 08/30/07 600 12 165 o 08/29/07 600 12 165 0 08/28/07 600 3 165 0 08/27/07 600 13 165 0 08/26/07 600 13 160 0 12131/2007 9:13 AM - TIO Reports 7e.xls J J Dolan CI_In~Rpt_GranitePt_Unocal_2007-09.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 800 c ~ 600 f ~9 5/8" 13 3/8" ! 700 ~ 20° Tubing 500 Vol 44-1 1 600 - 400 500 V14~ m d' Q1 L a 300 '- 200 200 '~~ 100 t 100 „~ 0 - -- n r n ~ ~ n n r~ n n ~ r n ~ n n r n ~ r~ r ~ n ~ n ~ r ~ n n 0 ~ O ~Op O_ O O O a I~ O M ~O_~pp ~O_~pp ~~_p O O O O O O O O O O O O O O O O O O c0 OI N N m ~ O th O ~ N N 4D M ~~_p ~~p_N_p N_p ~N_p O O O ~ ~ ~ ~ N N N c` O O O O O O O O O O O O O O O O O O O ~ N i/1 aD O ~ ~ ~ O O O O O O P `1 N O O O O f~ O N t7 O O p O O p O O O O O O Date 08/31 /07 08/30/07 08/29/07 08/28/07 08/27/07 08/26/07 08/25/07 08/24/07 08/23/07 08/22/07 08/21 /07 Tubing ' V014A-i1 TIO Report 12 12 160 0 1s5 o Data Sheet 12 165 0 13 ts5! o GP 44-11 13 180 a 13 13 165' o ant 1901 INJECTION 13 . 165 0 13 13 2101. 598 1 so; c Permit # 1670700 13 170 356 13 155 0 13 155 c API # 50-733-20059-00 13 155 160 13 t 55 ~ 0 06/01 /2007 to 08/31 /2007 13 13 155' 0 155L, 0 13 155 0 13 155 0 13 155; 0 13 15,5 U 13 155 0 13 160, 0 13 155 0 13 155 0 13 155 0 13 155'' 0 13 155 0 13 145j 0 13 155 0 13 1551 0 13 1801 0 13 160 0 13 160! 0 J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2007-08.x1s GP 44-11 12/31/2007 9:13 AM - TIO Reports 7e.xls ~~ Plot Pressure & Rate vs Time -Well GP 44-11 looo g c _ .. .,,,.. .., soo 900 ~9 5/8" {k 13 3/8" 700 20" f 800 { Tubing f ~ Vol 44-1 1 i 600 700 {{ 500 600 ~ N 500 _ - ~md, ~ a aoo 300 300 _ { 200 t 200 100 100 0 0 ~ ~ r r~ ~ n n ~ r~ r ~ n r ~ n r r ~ r ~ r ~ r r r~ ~ ~ ~ ~ r r o O O O O O o o O O O O O O O O O O O O O O O O O O O O o O O 0 O ~ O l f O f O th tD ~ N N aD C I~ p N v1 00 V f~ O c+l ~ W N ~1 m O I t\ _O O_ O ~_ ~_ ~_ N N_ c`l t` (O_p ~O_p ~O_p ~~_p ~~_p ~~_p ~N_p ~c`pI ~_Np ~N_p O O O ~ ~ ~ N N N N O O O O O O O ~ O ~ ~ ~ ~ 'n N ~ ~ p O O O p p O O O O O O O ~ O O O O O O O O O O O Date 1 3 3/8" 20" Tubing ~ Vol 4a-11' T10 R@pOrt 07/31/07 580 13 155 4' ~8t8 Sheet 07/30/07 570 13 155' 0 07/29/07 580 13 160 0 07/28/07 580 13 1601 0 07/27/07 580 13 160 0 GP 44-11 07126/07 580 13 160j 0' 07/25/07 580 13 160 0 INJECTION o7/2a/o7 580 13 160; o 07/23/07 580 13 170; 259 07/22!07 07/21/07 580 580 13 13 140 140 0 ~ P@~nllt # 1670700 07/20/07 580 13 1401 0 07/19/07 580 13 140 U API # 50-733-20059-00 07/18!07 580 13 1ao; o 07/17/07 580 13 140' 0, 07/16/07 580 13 143! 2 07/15/07 580 13 143'. 0 04/30/2007 to 07/31/2007 07114/07 580 13 143; Q'~ 07/13!07 580 13 143' 0' 07/12/07 580 13 143' 0 07/11/07 580 13 143i 0 07/10/07 580 13 143 0 07/09/07 580 13 145j C 07/08/07 580 13 142 ~ 0 07/07/07 560 13 145'. 0' 07/06/07 560 13 145 0' 07/05/07 560 13 1421 0 07/04/07 580 13 145 0 07/03/07 580 13 1451 0 07/02/07 580 13 1451 0 07/01/07 580 13 145' 0 06/30/07 580 13 145!, 0 06/29/07 580 13 145 0 06/28/07 580 13 1451 0 06/27/07 560 13 150. 0 06/26/07 560 13 155 0 12/31/2007 9:12 AM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2007-07.x1s GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 laoo i „~ aoo 900 ~9 5/B" I ~ 13 3/8" ~ 700 ®20.. Tubing _ 800 ~ Vol 44-1 1 __ 600 700 500 600 ; I d ~ y~ N ~ m E~ a s 400 300 300 200 200 - - _-- _- 100 100 0 0 r n r ~ ~ n ~ r~ ~ r O (h 0 n ~ ~ ~ r n ~ n ~ n r n r~ n r n r n ~ r ~ O O_ O O O O O O O O O O O O O O O O O O O O (7 ~ N UI ~ ? 1~ O fh t0 A (~ ~1 ~ V I~ O N ~ O O O ~ N N N O`) O O O ~ ~ ~- ~1 N N t`I O O 0 0 o g S~ S o$ o 0 0 0 0 0 0 0 0 0 0~~ O ~ ~ O O O O O ~ Q f~ O l~ ~ N N ~~~~~ O O f0 Of N N ~~ 580 580 580 560 560 570 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 560 570 570 570 580 570 580 580 20" robing ;Vol' ' 13 14~i~ 13 i45 13 145( 13 150' " 13 155 13 13 1551. 150 { 13 150 4 13 150~~' 13 1501 13 15US`; 13 150("` 13 150 13 150° 13 150(.. 13 150, 13 1501 13 150 13 150?'?" 13 150; 11 150' 13 150! 13 1501 13 1501 13 1601 13 160: 13 160': 13 1601 13 1601 13 160' 13 175- 367 13 150! 0 13 155? 0 13 160? 0 13 160' 0 13 160, , 0 TIO Report Data Sheet GP 44-11 INJECTION Permit # 1670700 API # 50-733-20059-00 03/31/2007 to 06/30/2007 12/31/2007 9'12 AM - TIO Reports 7e.xls J J Dolan CI_Inj_Rpt_GranitePt_Unocal_2007-06.x1s GP 44-11 1000 900 800 700 600 d 7 N r~ N d a aoa 300 200 100 800 700 600 500 d 300 200 100 0 0 n n O O n n n n n O O O O O n n O O n n n O O O n n O O n n n n n n O O O O O o n n n n n n r n n n n O O o O O O O O O O O V u D 0 O ~ ` N ~ O O m OD R n O O ~ ~ ~ N m M m n t7 f0 N N M 41 7 N O O m v v I~ O O ~ v v (~f t0 ~ N N m ~ ~_ ~ N (V N ] O ~ c < I O ( ~ t O O O ~ ~ ~ ~ N (V (V t`'1 M 0 0 m ~ 0 0 0 0 0 M 0 0 0 0 0 0 0 $ g O o ~ O o 0 0 0 0 0 0 0 0 0 0 Date ~- 518° 13 3l8" 20°' Tubing ,Vol x4.11' T~O RepOft 05/3 ~ 0 570 13 175 ' 367: Sheet ~8t8 05/30 U 570 13 150 0' ` 05/29/07 580 13 155 0: 05/28107 570 13 160 i 4 05/27/07 580 13 t6o o GP 44-11 05/26/07 580 13 160 G 05!25/07 580 13 170j ata o5/2a/o7 580 13 160, o INJECTION 05/23!07 580 13 1651. Q! 05/22/07 590 13 180! 462` 05/21/07 580 13 160! o. Permit # 1670700 05/20/07 590 13 165; U 05/19/07 600 13 200; 527{' o5ns/o7 5so 13 160! ~ API # 50-733-20059-00 05/17!07 600 13 175; 0''- 05/16l07 600 13 940!. 750: 05/15/07 590 13 165! 0 03/02/2007 to 05/31/2007 05/14107 600 13 170 05/13/07 590 13 170', a22 05/12!07 590 13 170 7Q0` 05/11/07 590 13 1701 05/10/07 595 13 170' 05/09/07 595 13 170; 517;,, 05/08/07 595 13 1701 U' 05/07/07 580 12 i 70 ~ 552 05/06/07 580 13 170 ~ 0 05/05/07 580 13 930' S64 05/04/07 560 13 150' tr 05/03/07 560 13 150 0 05/02/07 570 13 150 ` 0 05/01/07 560 13 150! a 04/30/07 560 13 150 i EI 04/29/07 560 13 1501 d+ 04/28/07 560 13 150; Q~ 04/27/07 560 13 150! 09 04/26/07 560 13 150!. 12/31/2007 9'12 AM - TIO Reports 7e.xls J J Dolan CI_InLRpt_GranitePt_Unocal_2007-OS.xls GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 Plot Pressure & Rate vs Time -Well GP 44-11 _,, ,,. .,,:,~ ,,. ,.. 1200 1000 _ _ ~ soo ~9 5/8" 1000 13 3/8" 800 ~~20" Tubing Vol 44-1 1 700 { i 800 600 L ~ Q~ 60>~ y ~~ ~ d a I 400 400 300 200 200 100 0 O r n n r r~ r ,^ I^ ~ ~ ~ ~p O a ~p ~p ~p ~p ~p r r I~ n n 1~ n n n I~ n O O o o O O O o O o 0 O O O O O r` o r O O O O O O O ' O ~ O s a O _ p 1~ O Nl t0 O O ~ ~ •- ` O~ N u"i aD M t0 01 N N CD Q I~ O (V ~ N N N In O O O ~ ~ ~ N N N (` O ~ O N m O N l ~ ( O I ~ ~ ~ N N N N N N C~ (7` N r r r r r r r r r r r N O O O O O O O O O O O O O O O O O O O Date 13 3/8" 20" Tubing ! VoI 4a-11 TIO Report 02/28/07 55o i3 18oj 571 Data Sheet 02/27/07 550 13 165( 0 02/26/07 550 13 200; asa 02/25/07 540 13 165j ~ 0 GP 44-11 02/24/07 540 13 20Ui 642 02/23/07 540 13 1701 0 02/22/07 540 13 930 40? INJECTION o2/2vo7 520 13 170; u 02/20/07 560 13 165 553 02/19/07 550 13 170j ; 0 Permit # 1670700 02/18/07 560 13 165 . 556 02/17/07 560 13 165i 9a0 02/16/07 560 13 165 0 API # 50-733-20059-00 02/15/07 5so 12 165; o 02/14/07 560 12 165[ 601 02/13/07 560 12 165;- 0 ' 12/01/2006 to 02/28/2007 02/12/07 550 i 3 165j 704 02/11/07 550 13 165! C 02/10/07 580 13 200 719 02/09/07 540 13 170j 0 02/08/07 540 13 200j 888 02/07/07 540 13 165; 0 02/06/07 540 13 195; 68i 02/05/07 540 13 165 0 02/04/07 540 13 180E 655 02/03/07 540 13 i65~ 0 02/02/07 540 13 1800 719 02/01/07 540 13 165 0 01 /31 /07 540 13 165. 889: 01 /30/07 550 13 1651 936 01!29/07 550 13 165) 0' 01/28/07 520 13 162; 0 01/27/07 520 13 14U~ t005. 01/26/07 520 {w 165' d 01/25/07 520 13 160 813 01 /24/07 520 13 165, o 12/31/2007 9:11 AM - TIO RepoRs 7e.xls J J Dolan CI_In~Rpt_GranitePt_Unocal_2007-02.x1s GP 44-11 Pressure N W l~ CT O v 00 O O O O O O O O O O O O O O O O O 8/31 /07 ~ I i i 9/03/07 i 9/06/07 ~ I'! ~ ~ I I I ' 9/09107 o ~ o w ~ I, ' A ~. ' W ~ 00 9/12/07 ~ j ~ _ ' I --- - 9/15/07 ~ r I 9/18/07 ~ ! ~' I 9/21 /07 i ' ~ 9/24/07 I _ O 9/27!07 ' I ~ ~ ~ ~ r „~ I k 9/30/07 , ~ ri 10/03/07 I ~ ~ 10/06/07 10/09/07 .~`~`~'~""" i /~ ~ A9 ~', 10/12/07. ~ ~ ~~ .. ~ µ ~ 10/15/07 K ! ~.~ ~~}"'~ ~ M", ~ 10/18/07 ~ ~ • ~ 10/21 /07 ~ rD i 10/24/07 10/27/07 C 10/30/07 ~ ~ ~ 11 /02/07 ~ 11 /05/07 ? ~ ', ~ ~-+ I ~ 11 /08/07 11/11/07 11 /14/07 11 /17/07 11 /20/07 j 11 /23/07 j 11 /26/07 I, ~ ' ,;, i ~ 11 /29/07 ° ° o Rate ° o iv ~ o o 0 0 0 0 0 O O O • • Pressure N ? 07 OD O N O O O O O O O O O O O O O 10/03/08 10/06/08 10/09/08 10/12/08 10/15/08 10/ 18/08 10/21 /08 ~~ - 10/24/08 10/27/08 I ( I 10/30/08 11 /02/08 N ~ w ~ 11 /05/08 -~~. 11 /08/08 cfl °o_ 11/11/08 - - 11 /14/08 b 11 /17/08 p 11 /20/08 ~'~' 11 /23/08 ~; b 11 /26/08 ~ 11 /29/08 ~ , ~ 12/02/08 ~ ~ 12/05/08 12/08/08 ~ 12/11 /08 ri~., ~G~ 12/14/08 12/17/08 12/20/08 A~ 12/23/08 '"~ ~ 12/26/08 12/29/08 ~ 1 /01 /09 y 1 /04/09 ,~. 1 /07/09 1 /10/09 rp 1/13/09 ~ ~ 1/16/09 1 /19/09 ~ 1 /22/09 ~~' ~ r•r 1 /25/09. '-' 1 /28/09 1 /31 /09 ~ b 2/03/09 ~ ~ 2/06/09 ~ ,~ 2/09/09 ~ 2/12/09 ~ -- ~ 2/15/09 2/18/09 , 2/21 /09 2/24/09 , 2/27/09 3/02/09 3/05/09 3/08109 3/11/09 . 3/ 14/09 3/17/09 3/20/09 3/23/09 3/26/09 3/29/09 4/01 /09 E O - N ~ `A - O O O O ~ _ ' ~ O O O ' J z c7 J c ~~I O • • ~ ~ , ~, ~ ~' ' ' ~ ' ~~ ~' ~ ~ ~ ' ' ~ ~., '~ `', ~ ; a ~ ~ ~+ ; ~ FRANK H. MURKOWSKI GOVERNOR ~: i' ~r oii0-7~1~ OIL AATI) GA,S 333 W. 7"' AVENUE, SUITE 100 CO~-7ER~AliOls CO~II-7SIOR ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection. orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. • • Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Inte 'ty" Confinement" Area Injection Orders AIO 1 -Duck Island Unit 6 7 9 AIO 2B - Kupanxk River Unit; Kuparuk River, Tabasco, Ugnu, West Sak 6 ~ 9 Fields AIO 3 -Prudhoe Bay Unit; Western Operating Area 6 ~ 9 AIO 4C -Prudhoe Bay Unit; Eastern Operating Area 6 ~ 9 AIO 5 -Trading Bay Unit; McArthur River Field 6 6 9 AIO 6 -Granite Point Field; Northern Portion 6 ~ 9 AIO 7 -Middle Ground Shoal; Northern Portion 6 ~ 9 AIO 8 -Middle Ground Shoal; Southern Portion 6 ~ 9 AIO 9 -Middle Ground Shoal; Central Portion 6 ~ 9 AIO 1 OB -Milne Point Unit; Schrader Bluff, Sag River, 4 5 g Kuparuk River Pools AIO 11 -Granite Point Field; Southern Portion 5 6 8 AIO 12 -Trading Bay Field; Southern Portion 5 6 8 AIO 13A -Swanson River Unit 6 ~ 9 AIO 14A -Prudhoe Bay Unit; Niakuk Oil Pool 4 5 8 AIO 15 -West McArthur 5 6 - 9 1 • Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrit " Confinement" River Unit AIO 16 - Kuparuk River Unit; Tarn Oil Pool 6 7 10 AIO 17 - Badami Unit 5 6 g AIO 18A -Colville River Unit; Alpine Oil Pool 6 7 11 AIO 19 -Duck Island Unit; Eider Oil Pool 5 6 9 AIO 20 -Prudhoe Bay Unit; Midnight Sun Oil Pool 5 6 9 AIO Z 1 - Kuparuk River Unit; Meltwater Oil Pool 4 No rule 6 AIO 22C -Prudhoe Bay Unit; Aurora Oil Pool 5 No rule 8 AIO 23 - Northstar Unit 5 6 9 AIO 24 -Prudhoe Bay Unit; Borealis Oil Pool 5 No rule 9 AIO 25 -Prudhoe Bay Unit; Polaris Oil Pool 6 g 13 AIO 26 -Prudhoe Bay Unit; Orion Oil Pool 6 No rule 13 Dis osal In'ection Orders DIO 1 -Kenai Unit; KU WD-1 No rule No rule No rule DIO 2 -Kenai Unit; KU 14- 4 No rule No rule No rule DIO 3 -Beluga River Gas Field; BR WD-1 No rule No rule No rule DIO 4 -Beaver Creek Unit; BC-2 No rule No rule No rule DIO 5 -Barrow Gas Field; South Barrow #5 No rule No rule No rule DIO 6 -Lewis River Gas Field; WD-1 No rule No rule 3 DIO 7 -West McArthur River Unit; WMRU D-1 2 3 5 DIO 8 -Beaver Creek Unit; BC-3 2 3 5 DIO 9 -Kenai Unit; KU 11- 17 2 3 4 DIO 10 -Granite Point Field; GP 44-11 2 3 5 • • Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" DIO 11 -Kenai Unit; KU 24-7 2 3 4 DIO 12 - Badami Unit; WD- 1, WD-2 2 3 5 DIO 13 -North Trading Bay Unit; S-4 2 3 6 DIO 14 -Houston Gas Field; Well #3 2 3 5 DIO 15 -North Trading Bay Unit; S-5 2 3 Rule not numbered DIO 16 -West McArthur River Unit; WMRU 4D 2 3 5 DIO 17 -North Cook Inlet Unit; NCN A-12 2 3 6 DIO 19 -Granite Point Field; W. Granite Point State 3 4 6 17587 #3 DIO 20 -Pioneer Unit; Well 1702-15DA WDW 3 4 6 DIO 21 - Flaxman Island; Alaska State A-2 3 4 7 DIO 22 -Redoubt Unit; RU D1 3 No rule 6 DIO 23 -Ivan River Unit; IRU 14-31 No rule No rule 6 DIO 24 - Nicolai Creek Unit; NCU #5 Order expired DIO 25 -Sterling Unit; SU 43-9 3 4 7 DIO 26 - Kustatan Field; KF 1 3 4 7 Storage In'ection Orders SIO 1 -Prudhoe Bay Unit, Point McIntyre Field #6 No rule No rule No rule SIO 2A- Swanson River Unit; KGSF # 1 2 No rule 6 SIO 3 -Swanson River Unit; KGSF #2 2 No rule 7 Enhanced Recover In'ection Orders EIO 1 -Prudhoe Bay Unit; Prudhoe Bay Field, Schrader No rule No rule g B1uffFormation Well V-105 • Injection Order EIO 2 -Redoubt Unit; RU-6 "Demonstration of Mechanical 5 • Affected Rules "Well Integrity Failure and Confinement" 8 "Administrative Action" 9 02-902 (Rev. 3/94) STATE OF ALASKA ADVERTISING ORDER SEE'BOTTflWI FOR tNVO1CE ADDF F l AOGCC R 333 West 7th Avenue, Suite 100 ° Anchorage, AK 99501 "I 907-793-1221 o Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AK 99518 Receiving AGENCY CONTACT ~7V / ~ / 7J - I GL I DATES ADVERTISEMENT REQUIRED: October 3, 2004 DATE OF A.O. AO FRM THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL [NSTRCCTIONS: ~ AFFIDAVIT OF PUBLICATION United states of America State of ss division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for consecutive days, the last publication appearing on the day of .2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This -day of 2004, Notary public for state of My commission expires _ REMINDER INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO_02514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF M ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE Public Notices Subject: Public Notices From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 29 Sep -2004 13:01:04 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren_mcver@dmin_state.ak.us> Angela ~~ ebh <angie_webb@admin.state.ak.us>, Robert E Mintz <robert_mintz(u;la~~.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@:bp.cum>, Sondra Ste~uman <StewmaSD@BPcom> Scott & Camy Taylor <staylar@alaskanet>, stanekj <stanekj@unocaLcom>, ecola~v <ecolaw~a trustees.org> roseragsdale -'roseragsdale@ci.net>, trmjrl <trmjrl@aoLcom>, jbrddle <jBriddle@marathanoil.com>, rockhill <ruckhill@aoga.org>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@arestoiLcom>, nels~~n <knelson@etroleumnews.com>, ebaddy <cboddy@usibetli.a~m>, M~u-k Dalton <mark.dalton@hdrine.com>, Shannon:DannellyCShannon.donnelltiiciconocophillps.corn>; "Mark P. Worcester" <mark;p.warcester@conocophillips.eain>, "J~;rry C. Detl~l~fs" <ferry.c.dethlefs@conocophillps.cam>, Bob <bob@inletkeeper.org>, ~.udv <<~~~d~~~dnr.state.ak.us> tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@laslca.net>, mjnelson <mjnelsc~n ci~purvingertz.corn> Charles O'Donnell ccharles.o`donnell@veco.com>, "Randy L. Skill.ern" <Ski11eRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.cam>, "Paul G. Hyatt" <hyattpgex,BP.com~, "Steven R. Rassberg" <RossbeRS@BP.com>, Lais <lois@nletkeeper.org>, Dan Bross <kuacnews(~rkuac.org>, Gordon Pospisil <Pa'spisG~aBP.com>, "Francis' S. Sommer" <SommerFS(a~;BP.com>, Mikel Sehdltz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverN@'!a;;BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.eortl>,"Janet D. Platt" <PlattJD~a7BF.eom~, "Rosanne ~'[. Jacobsen" <JacobsRM@BP.cam>, ddonkei <ddonkel@cfl.rr.com>,;; Collins Mount <collins mount@revenue.state.ak.us>, mckay <mckay@gci.rtet>, Barbrlra F Fullmer <Barbara.f.fullmer@conocophillips.com> bocastwf <bacastwf@bp.corn>. Charles. Barker <barker@usgs.gov?, doug_schultze <doug_sehultze@xtoenergy.conl~-, Hank Alfi~rd <hank.alford@exxanmobil.eam>, Mark Kavac <yesnol@gci.net~; ~~spfoff <gspfoff@aurorapower.com ~, Gregg Nady <gregg.nady@shell.cuin>, Fred Steece <fred.steece@tate.sd.us>, rcrotty<rcrotty@ch2m.com>,,jejones <jejones~aaurorapo~uer.com?, dapa <dapa@alaska.net>, jroderick <jrod:erick@ei.net>, eyancy ~eyancy(~i.:seal-tite.net%, ".Fames M. Ruud" <fames.m.nzud@~onocophillps.cam>, Brit Lively <mapalaska(a(:.net>, fah <jah@nr.state.ak.us>, Kurt E Olson <kart_oson@legis.state.ak.us==~, buunoje ~==buonoie~u;@.cum>, Mark Hanley <mark hanle@anadarko.com>, loren_leman <luren leman!a:;gov.state.ak.us>, Jttiie Houle <jule_houle@dnr.state.ak.us> John W Katz: <jwkatz(u~sso.arg=>, Swan J Hill <suzan hill@ec.state.ak.us>, tablerk <tablerk@unocal.cc~m>, Brady ~~brad@ao~a.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@bort~ugh.kenai.ak.us'=, Jim ~'~rhite jimwhite@s~atx.rr.com>,`''JoI~S. Haworth" <johna:haworth~cL,exronmobil.com>, mariy <marty@rkindustrial.cum>, ghammons <ghammans~u)aol.com>, rrnclean <rmclean@p~BoYalaska.net>, mkm7200 <mkm7200@~adl.com>, Brian Gillespie ~ifb@@uaa.alaska:edu>, David L Boelens <dboelens@aurarapo~~-er.com==, Todd Durkee <TDt71ZKEE@KMG.com;>, Gary Schultz <gary_schult@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.~.a-, Bill Miller <Bill Miller~;xtoalaska.com=>. Brandon Gagnon <bgagnon@hrenaiaw.cam>, Paul Winslow'<pmwnslow@ forestoiLcom= , Gam Catron <catrongr@bp.cam>, Sharmaine Copeland <copelasv(a},bp.com~, Suzanne Allexan <sallexan@heimenergy.com=•. Kristin Dirks <kristindirks(-i dnr.state.ak.us>, ltaynell Zeman. <kjzeman@n~arathonoiLcom>, John'I'c~wer ~John.Tower~cr),eia.doe.gov~, Bill Fowler <Bill_Fowler@anadarko.COM> Vaughn Swartz <vaughn.s~~~artz arbccm.com>, Scott Cranswick 1 of 2 9/29/2004 1:10 PM I Public Notices • <scott.cranswick@mrn .goo>, Brad McI~ixn <mcki~nbs@EP.eom> Please find the attached Notice and Attachment for the proposed amendment oi= underground injection orders and the Public Notice I-tappy Valley #10. Jody Colombie Content-Type: appiication,!msward iNlechaneal Integrity proposal.doc Content-Encoding: base64 Content-Type: application/msword .Mechanical Integrity of Wells Natice.doc ~~ Content-Encoding: base64 Content-Type: appiication/msword H appyV alley! 0_HearingNatice.doc Content-Encoding: base64 2 of 2 9!29!2004 1:10 PM __ Public Notice Subject: Public Notice From: Jody Colombie <Jody_colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 12:55:26 -0800 To: legalCalaskajournal;com Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content-Type: application/msword Mechanical Integrity of Wells Notice.doc Content-Encoding: base64 _ __ ___ _ ._ __ __......._ ......................_.._...... _. _._............_._._. _....__._... ................ __ _ _ ___ Content-Type: application/msword Ad Order form.doc- Content-Encoding: base64 I of 1 9/29/2004 1:20 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 1.29 Barrow, AK 99723 • Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 ~~~~~ ~~ David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marpfe's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 [Fwd: Re: Consistent Wording for Injection~rs -Well Integrity Subj;eet: [Fwd: Re Consistent Wording for Injection Orders - From: John 1Vorman <john_norman@admin.state.ak.us> Date: Fri; 01 Oct 2004 11:09:26 -0800 To: Jody J Colombie <Jody colombie@,admin.state.ak.us> more • Well Integrity (Revised)], ------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders -Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintz(c~law.state.ak.us> To:jim regg(a~adrnin.state.ak.us CC:dan seamount(u,admin.state.ak.us, john norman(c~,adrnin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <jim re~g(c~admin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob -Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: ', Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim reQg(aadmin.state.ak.us> 8/17/2004 4:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing 1 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injectior>~rs -Well Integrity ... - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retittes to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); -consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid. escape from disposal zone" Jim Regg __ John K. Norman <John Norman(a~admin.state.us> '': Commissioner Alaska Oil & Gas Conservation Commission 2 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection ~s -Well Integrity ... Subject: [Fwd: Re: Consistent Wording for Injection Orders - Well Integrity (Revised)] From: John Norman <john_norman@adminatate.ak.us> Date: Fri, O1 Oct 2004 11:08:55 -0800 To: JadyJ Coiombie <jody_colombie a~adminstate.ak.us> please print all and put in file for me to review just prior to hearing on these amendments. thanx ------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - WeII Integrity (Revised) Date:Thu, 19 Aug 2004 15:46:31 -0800 From:Rob Mintz <robert mintz~law.state.ak.us> To:dan seamount(a~admin.state.ak.us, jim regg(a~admin.state.ak.us, john normannaadmin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers wilt be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg dim regg~admin.state.ak.us> 8/17/2004 4:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions 1 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injectio~rs -Well Integrity ... - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); -consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman(a~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission Content-Type: application/msword ,'Injection Order language - questions.doc' Content-Encoding: base64 Content-Type: application/msword ,Injection Orders language edits.doc Content-Encoding: base64 ___: 2 of 2 10/2/2004 4:07 PM • • Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubin /g Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. • • Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tobin /g_Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (e~ccept at least once every two years in the case of a slurry inf ection well), and before returnin~a well to sen~ice follo`vin~ ~ a workover affecting mechanical integrity, ~_..a ~+ , __::*_ .,.._.. _ . _ ,, . ~..., .: ~:':. u~*:. ~ ~ • .. +• ~,,,. ~,,,~.~, •~ ~~ ~ ~' tTnless an alternate z~zeans is approved by the Commission mechanical integrity must be demonstrated by a hzbin~ pressure test using a ~ ~1-surface pressure of~~ 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, t11at t~rtz~shows stabilizing pressure that doesar~;a not change more than 10°=e- ep rcent during a 30 minute period. -14~w The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Inte rite Failure and Confinement Exi;ept as otherwise provided in this rule Tthe tubing, casing and packer of an injection well must d,~n<~=t€--maintain integrity during operation. E~Thenever any pressure communication, leakage or lack of infection zone isolation is indicated by infection rate operatin; pressure observation, test, survey, log, or other evidence the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval_ ~j~-+ .,+ r ~.~~;n`_~,re3° 1,." +•, ~ f_ +7 . ~ ~ The operator shall shut in the dvell if so directed by the Commission. The operator shat l shut in the well without awaitin a response f~i-om the Commission if continued operation would be unsafe or would threaten contamination of freshwater Crt z " +' " + ' z, ~ Until~corrective action is successfully ~... cozn le~tecJ. Aa monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. , [Fwd: Re: [Fwd: AOGCC Proposed WI L for Injectors]) Subject: [Fwd: Re: [Fwd: AOGCCPropgsed WI Language for Injectors]] From: Winton Aubert <winton au6ert@admin.state.ak:us> Date: Thu, 28 Oct 2004 09:48:53 -0800 To: Jady J Colomhie <Jody_colombie@admin.state.ak.us> This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- Subject: AOGCC Proposed WI Language for Injectors Date: Tue, 19 Oct 2004 13:49:33 -0800 From: Engel, Harry R <EngelHR@BP.com> To: winton aubert@admin.state.ak.us Winton... Here are the comments we discussed, Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry R; Cismoski, Doug A; NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.; Reeves, Donald F; Dube, Anna T; NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before* ** 1 of 3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI L~ for Injectors]] return'_ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall_* immediately*_** notify the Commission" This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A; Digert, Scott A; Denis, John R (ANC); Miller, Mike E; McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [mailto:jody colombie@admin.state.ak.us ] Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal.ZIP» «Mechanical Integrity of Wells Notice.doc » 2 of 3 10/28/2004 11:09 AM • _'~ ~ e e ~ ;~ ' 1~ I ~ ~ `i , ' j ~ {"W 1 ~`t ~ ~ ~ i ~ i } ~~.~ I ~ ~ ~ k ~ ~ t t S ~ f 4. 1 Ee .,3' s } { i e ~ 4 S I - ~ S ~ S T f i P~ .s..v,_- .~ ~s .. .. . Sv..r° ~. ~ ~ ~ f ~ ,--, °_ vi40-7~ O~ ~ spa COI~TSER~ATIOI~T COrII-TISSIOl~ September 24, 2004 Ms. Laura L. Hammond Waste Management Coordinator Unocal Alaska 909 West 9`h Avenue Anchorage, AK 99501 Dear Ms. Hammond: • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~'~ /a. c~G~ Unocal Alaska ("Unocal") requested by letter dated May 21, 2004, confirmation of the Class II status of certain fluids that will be generated during the integrity investigations of the gathering line between Granite Point Platform and the Granite Point Tank Farm. Unocal intends to clean and smart pig the line as part of their Pipeline Integrity Management Program. The cleaning process will use natural gas to remove condensate, and filtered inlet water with cleaning chemicals; the smart pigging process will use filtered inlet water to push the smart pig. The final step will require the use of up to 1,000 gallons of methanol to dry the pipeline prior to returning the line to gas service. Disposal Injection. Order. l0 authorizes the disposal injection of Class II fluids into Granite Point Field well 44-11. Fluids generated during this maintenance process will include produced water, residual hydrocarbon, solution of cleaning chemicals and filtered inlet water, hydrocarbon contaminated particulates, and used methanol. Unocal provided additional clarification by electronic mail dated June 24, 2004, and during a meeting held on September 14, 2004, noting that the methanol is critical to the success of this integrity program since there is an insufficient volume of gas to dry the pipeline. Unocal further clarified that injecting the methanol and water used in the cleaning and pigging process as a replacement for enhanced recovery operations was an undesirable option given the piping arrangement and design of the Granite Point Platform separation system; attempting to inject the water and methanol into the enhanced recovery wells could result in a "potentially large portion going directly into the inlet with associated hydrocarbon containment." Unocal's concern with overboard discharge is the potential to exceed the outfali limits imposed by an existing National Pollutant Discharge Elimination System permit. The Alaska Oil and Gas Conservation Commission ("Commission") has completed its review of your request. The Commission is convinced the methanol-water mix generated from drying the Granite Point gathering line is a necessary part of continued flow assurance for the Granite Point gathering line, and the waste is integral to the pigging process. • • Ms. Laura L. Hammond Waste Management Coordinator September 24, 2004 Page 2 of 2 The Commission confirms that fluids, as described, are eligible for disposal injection into Granite Point Field well 44-11. Prior to injection Unocal must confirm the continued inte it of the injection well Order "' ~' Y with a mechanical integrity test as outlined in Rule 2 of Disposal Injection -~ ,, ;` ~ l1 U` i, ~`-< Daniel T. Seamount, Jr. Commissioner Chairman METHANOL SA E N RAN P U G A G ITE P GAS PI ELINE UNOCAL 76 -~~~Alaska PROPOSED USAGE OF METHANOL ON GRANITE POINT PLATFORM GAS PIPELINE Unocal intends to perform an Ultrasonic In-Line Inspection of the Granite Point Gas Pipeline by using an instrumented pig propelled by water from Granite Point Platform to Granite Point Tank Farm. The intent of the inspection is to obtain information on the condition of the pipeline, specifically to detect the presence of corrosion in the pipeline. This information will be used to ensure the pipeline is acceptable for continued production and to identify any detrimental anomalies which may require remediation. The Ultrasonic tool requires a homogeneous liquid medium to operate correctly. This is because the speed of sound through the medium must be constant for the inspection tool to accurately measure the thickness of the pipe wall. Filtered inlet water has been selected as the medium for performing this inspection. Upon completion of the inspection, the water must be removed from the pipeline prior to returning to normal gas operations. The pipeline will be de-watered from the onshore facility with a pig propelled by gas. This operation will remove most of the water from the pipeline, but residual water will remain in the pipeline. It is critical to remove the residual water for two primary reasons. Gas contaminated with water will not burn cleanly and may damage gas-fired equipment. In addition, water must be removed from the pipeline to minimize the corrosive properties of the internal pipeline environment, thereby preserving integrity for continued operation. Methanol has been selected as the drying agent for this pipeline. Methanol is highly effective at absorbing water and poses minimal risk beyond its flammable nature. 40 CFR Part 261 Subpart A §261.4 describes materials which are not considered hazardous wastes. The applicable section reads: (b) Solid wastes which are not hazardous wastes. The following solid wastes are not hazardous wastes: (5) Drilling fluids, produced waters, and other wastes associated with the exploration, development, or production of crude oil, natural gas or geothermal energy. ~COFFMAN 9/14/2004 GPP METHANOL USAGE.DOC N G I N E E R S • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION TOPIC: ~ ~ ~5~~ e\io~ ~\v~~S P DATE: S2 ~ \~ 1~C~O~ TIME: ~~~ NAME -AFFILIATION ADDRESS/PHONE NUMBER TESTI ~ s or No (PLEASE PRINT) r~,~. ; a,Z , 7- ~- y„x~ G,a~ ~ 3 • X830 ~~~'~f~~~ ~o~~t~l~ ~~N ~~ ~ ~~~ - ~~~~ ~armn SI~,,.,1.~,. ~o~~~~ ,~na~~ec~s Z~G-666`[ ~.., au.~ra- ~-l awe w~o~v b u~ ac~Z. ~ ~ 3 -' ~S 18 ,FYU~ cc~ '~) uVleeting Sign-In SUN-02-2004 WED 12;26 PM UNOCAL ALASKA FAX N0. 907 263 7874 P, 02 ~~OCA~ 7~ Laura L. Hammond °`a~°~i~ Alaska Waste Management CoordinaEor Unocal Alaska Te1907.263.7898 Fax 907.263.7884 CeA 907.398.9900 e-mail Ihammond(D u nocal.com May 21, 2004 Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Re: Confirmation of Class II Status of Fluids From Gathering Line at Granite Point Platform Dear Commissioner Norman: Purpose: The purpose of this le#ter is to request. your confirmation of the Class 11 status of certain fluids that will be generated as an integral part of our production operations as we perform integrity testing and maintenance on one of our gathering lines at Granite Point Platform. In this case, the fluids used to perform this integrity testing and maintenance activity wi(I be in contact during their normal use with liquids, solids, and gases that originated downhole and are subject to EPA's Exploration and Production Exemption from Resource Conservation and Recovery Act (RCRA) Subtitle C regulation. What Unocal Proposes To Do: Unocal is preparing to Smart Pig the gathering line between the Granite Point Platform (GPP) and the Granite Point Tank Farm as part of our Pipeline Integrity Management Program. This gathering line is typicaliy in gas service. The following steps will. be undertaken: 1. We will remove condensate from the pipeline by pigging it to GPP with natural gas. The condensate from this operation will be routed to crude oil sales through the Platform tank and piping systems. Condensate may be routed either through the Waste Water Tank and skimmed into the crude tank or routed through the separator and crude tank or other piping systems depending on operational requirements. Union Oft Company of California 1 Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 hltp;//www.Unocal.com _ ~41N-D2-2004 WED 12 26 PM UNOCAL ALASKA FRX N0. 907 263 7874 P, 03 ,. 2. The pipeline wilt be cleaned by pushing filtered Inlet Water and cleaning chemicals (Baker-Petrolite "Surf Sweep") to Granite Point Tank Farm (GPTF}. The fluid will be temporarily stored in an available tank and then processed to produce the hydrocarbon phase. The aqueous phase will be outfalled in compliance with Unocal's existing National Pollutant Discharge Elimination System (NPDES} Permit. 3. After cleaning the pipeline, the Smart Pig pipeline inspection tool will be pushed from GPP to GPTF with water from the GPP watertlood system. 4. Once the Smart Pig is removed at GPTF the direction of flow in the pipeline will be reversed and the #iltered inlet water that has been in contact with the inside of the pipeline and any residual produced solids and fluids contained in the pipeline will be pushed back to the GPP with approximately 1,000 gallons of methanol between the water and the natural gas used to push the fluid back to GPP. The purpose of the methanol is to dry the gas pipeline after the Smart Pigging and avoid. leaving any residual water in the gathering line that might contribute to the formation of corrosion microclimates. Unocal respectfully requests that the AOGCC confirm that these fluids are in contact during their normal use with liquids, solids, and gases that originated downhole and the fluids can be considered an integral part of production operations and that therefore .they are legal Class II injectables. Thank you very much for your consideration of these matters. Best regards, Laura L. Hammond cc: Mr. Torn Maunder, AOGCC • • Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Union Oil Company of California (Unocal) for an order allowing the underground disposal of Class II fluids by injection into the GP 44-11 well in the Granite Point Oil Field. Unocal, by letter dated April 6, 1995, has requested the Alaska Oil And Gas Conservation Commission to issue an order in conformance with 20 AAC 25.252. The order would authorize the disposal of Class II fluids by injection into the Upper Tyonek Formation in well GP 44-11 at the Granite Point Oil Field, an offshore oil field in the Cook Inlet, in Southcentrat Alaska. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM April 28, 1995 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 AM on May 23, 1995 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433 after April 28, 1995. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than May 17, 1995. Russell A. Douglass Commissioner Published April 13, 1995 #13232 STOF 0330 AFFIDAVIT O F PUBLIC TAO N AO-0251446 $158.00 w/ STATE OF ALASKA, ) _wet(ce'of Publk (YeW'ing ~~ IY :stare of ae.asfca t'~ THIRD UDICIAL DISTRICT. ) Alaskd Oii and Gas I ~ U J Conservation caromissian Re The i' EVa M, Kd 11 ~Fll~AJl • app ~cat~on of Unynr Oll Company of Californic ., ............ ... . .............. tUnotal) for an order atiosving bein first dul sworn on oath y •rne underground disposot of Closs tl funds by infection into deposes and says that he/she is I the 6P 41.11 well in the Granl~ an advertising representative of Point bil Field. Unocal,, by letter dated April the Anchorage Daily News, a 6, 199$, has riquosfed the AraS- ka oh and Gas conservation daily newspaper. That said Comrrwssion to issue an order In ~cxfnforrrronce with 20 AAC 25. news a er has been a roved p p PP 12.52• The arderwould auttwrfze m ecto °int 4t~ ~ by the Third Judicial Court, i r o ups 1 +ronek IFormgtion in,weii GP 4t-trot Anchorage, Alaska, and it now . `i+~ Grc~,fte Poiro oil ~;eid, ~, and has been published in the offsfWre otl field in the Cook , tniet, fn soutlx~troi at~ica: English language continually as a A persai who may be harmed ~ if the requesfed order Fs issued daily newspaper in Anchorage, may fife d written. prate9tpr10r Ito a:oo pay Aprit 38: ~99s-with Alaska, and it is now and durin g ~~ ai©ska Oit anct Gas Goriser- al I said time was printed in an va}i0h Commission, 3D01 Porcu- Pine privet •anchorage, Aidska office maintained at the aforesaid 99501,=and requesf'o heartng.gn m ~ an r ~ place of publication of Sald ~ tt ete t a raises a s stanfiai cxtcl mgtecial issue cru- news a er. That the annexed is p p ~ C10i to the commission's defer. matt rs w t b o a copy of an advertisement as it e ill e eid f the pbovm i address ar 9:00 ann on May 23,' was published in regular issues 199s in conformance with 20 aac zs.sao, tf a heai•mg is to be I (and not in supplemental form) of held, interested Parties roar said newspaper on confirm this by: Calling the Com- o teri c G j t 90 2 ~ ~ f I , 2a i~s 1 f no st j oro+e April 13 r 1995 is ftted, The Commission will j confider the :issuance of the; order. without 6 hearing. I If You. are a person whh disabiliTy who may need a spe~ vial modificafion in order fa ~ Comment Or t0 aflend the pab1lC l . 1 klearing, plea3eC(N11aC1 1)1a11a1 Fleck nr 9w_le9r .... , __ . and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. _ ~ i,~ Subscribed and sworn to b~f6 e me this ~~ day .......... ....... 19~~( ~~. Notary Public in and for the State of Alaska. Third DNision. Anchorage, Alaska MY COMMISSION EXPIRES . s°..... ~ ................... ~ 9q.~ ~aliglasS b 1995 ilnocal Energy Res Division Unocal Corporation 909 West 9th Avenue, Pu. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Health, Environmental, Safety Alaska Business Unit Apri16, 1995 Mr. David W. Johnston Chairman, AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 Dear Mr. Johnston: Union Oil Company of California, dba Unocal, requests permission to dispose of non- hazardous oil field wastes by deep-hole injection into Granite Point well 44-11. The non-hazardous oil field wastes will include both solid (in slurry form) and fluid wastes that have been generated directly from normal drilling and production operations into Granite Point we1144-11. The primary purpose for the proposed injection well will be for disposal of drilling mud and cuttings. Area Injection Order No. 11 provides an exemption for aquifers below beneath Cook Inlet, described by a 1/4 mile area beyond and lying directly below the Granite Point Field. This exemption fulfills the requirements for Class II injection activities. The Application for Underground Injection for GP 44-11 is attached to this letter and fulfills information requirements of 20 AAC 25.252. If you have any questions regarding the application please contact me at 263-7832. Thank you for your assistance with this matter. Sincerely, Alice Bullin ton ~ R E C g EIVED Environmental Scientist APR - ~ 1995 Alaska uu & Gas Cons. ~pRlfrlISSIGII Anchorage Attachments cc Norm Smith, Mobil Oil Company John Beitia/File George Buck :7 RECEIVED APR - 7 1995 gi~~ Oil & Gas Cons.. Commission MchoraYQ • • APPLICATION UNDERGROUND INJECTION WELL GRANITE POINT 44-11 Submitted by Union Oil of California Apri16, 1995 RECEIVED APR - 7 1995 ~ UU ~ Gas Cons. Cpmt~t~Od Mchorao 1 • • APPLICATION FOR UNDERGROUND INJECTION GRANITE POINT FIELD WELL 44-11 Union Oil of California, dba Unocal, requests that the AOGCC issue a disposal injection order authorizing GP 44-11 to be used as a Class II disposal well in accordance with 20 AAC 25.252. Well # 44-11 was originally drilled to the west of the structure. When no pay sands were encountered the lower portion of the hole was abandoned and the well was suspended. The downhole location of this well makes it a poor redrill candidate. The well has no further utility as an oil producer. Well # 44-11 will be converted to injection using a coiled tubing unit and a jacking unit as outlined in the procedure found in Appendix A. The mechanical integrity of the well will be ensured with a pressure test . The cement bond will be proven using a cement bond log (USIT). Should the top of cement prove to be lower than the proposed receiving zone a deeper receiving zone will be selected in this well or a new well will be drilled for a similar purpose. 20 AAC 25.252(c)(1) Appendix B contains a plat showing the location of the proposed disposal well including abandoned wells, production wells, dry holes, and any other wells that penetrate the injection zone within one-quarter mile of the disposal well. 20 AAC 25.252(c)(2) Unocal operates Granite Point Platform which is jointly owned by Mobil Oil Company and Unocal. Unocal owns and operates all other facilities within aone-quarter mile radius of GP 44-11 (see map in Appendix C). 20 AAC 25.252(c)(3) Appendix C contains an affidavit showing that the operators and surface owners within a one-quarter mile radius have been provided a copy of the application for disposal. 20 AAC 25.252(c)(4) Appendix C contains geological information for the Granite Point Field. Afresh-water exemption zone has been established for the Granite Point Field. 20 AAC 25.252(c)(5) The log for GP 44-11 is on file with the AOGCC. 20 AAC 25.252(c)(6) A well schematic showing the proposed injection zone for we1144-11 is included in Appendix A. A mechanical integrity test (MIT) will be completed after the well is converted. A copy of the MIT will be made available to the AOGCC. • • 20 AAC 25.252(c)('n Unocal plans to inject non-hazardous fluids associated with drilling, production and workover operations. Such fluids may include, but are not limited to: • Produced Water • Drilling/Completion Fluids • Workover Fluids • Equipment Washdown • Drilling Mud Slurries • Norm Scale The primary purpose of the disposal well is for disposal of oil based drilling fluids and drill cuttings. The composition of the fluids will vary. A representative oil-based mud composition is included in Appendix D. The primary source of the fluids will be from seven (7) wells to be drilled on the Granite Point Platform. However, Unocal plans to dispose of similar fluids produced from other oil and gas facilities in Alaska. Unocal estimates the maximum daily volume to be injected should not exceed 3,000 bbls per day. 20 AAC 25.252(c)(8) The estimated average injection pressure will be 2498 psi. The estimated maximum injection pressure is 3500 psi. 20 AAC 25.252(c)(9) Appendix E includes an analysis of the potential fracturing from injection activities. Based on the fracture model simulation, fracture propagation is not expected to occur to any fresh water zones. 20 AAC 25.252(c)(10) Actual analysis of the formation water from GP 44-11 is not available; however, formation water salinity based on the log analysis is included in Appendix B. 20 AAC 25.252(c)(11) A Freshwater Exemption has been previously granted for the Granite Point Field. Area Injection Order No. 11 (Appendix F) provides an exemption for aquifers below beneath Cook Inlet, described by a 1/4 mile area beyond and lying directly below the Granite Point Field. This exemption fulfills the requirements for Class II injection activities. The proposed injection zone is located at 4642 feet TVDSS to 4980 feet TVDSS. 20 AAC 25.252(d) Unocal will perform a mechanical integrity test (MIT) (in compliance with 42 U.S.C. 300h-4 and 20 AAC 25.412) on GP 44-11 prior to operation and will report the results • of the MIT to the AOGCC. The annulus pressure will be monitored and reported monthly on the Monthly Injection Report (AOGCC Form 10-406) 20 AAC 25.252(h) There are two wells which penetrate the receiving zone within cone-quarter mile radius of a the location where well # 44-11 penetrated the zone. These two wells are the MUCI-2 well and the 31-14 well. Both wells will be monitored in order to ensure that they do not provide a mechanism for unacceptable fluid movement. MUCI-2 had 13-3/8" casing set at 3788' TVDSS and was cemented with 642 sxs. It had 9-5/8" casing set at 8297' TVDSS and was cemented with 600 sxs. The 9-5/8" x 13-3/8" annulus will be monitored on a daily basis during the injection program for pressure increases which indicate fluid movement. Well #31-14 had 13-3/8" casing set at 2106' TVDSS and was cemented with 1100 sxs. It had 9-5/8" casing set at 4344' TVDSS and was cemented with 675 sxs of cement. Once again the 9-5/8" x 13-3/8" annulus will be monitored on a daily basis during the injection program for pressure increases which indicate fluid movement. file: 0330gppi.doc • Appendix A STATE OF ALASKA A OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 1. Type Of request: Abandon _ _ Suspend _ Operations shutdown _ Re-enter suspended weilX__ Alter casing- Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program - Pull tubing _ Variance Perforate _ OtherX 2. Name of Operator _ 5. Type of Well: 6. Datum elevation (DF or KB) Development UNION OIL COMPANY OF CALIFORNIA UNOCAL _ Exploratory KB 105 feet 3. Address _ stratiyrapnic _ 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 _ service X__ Union-Mobil State #1 4. Location of well at surtace Granite Point Platform, Leg #1, Slot 2. 8. Well number 2360' S & 1261' E F/NW Corner Sec. 13, T10N, R12W, S.M. 44-11 ADL-18761 At top of productive interval 9. Permit number 67-70 At effective depth 10. API number 50-133-20059 At total depth 11. Field/Pool 3206' N & 2109' W of surface location Granite Pt. /Middle Kenai 12. Present well condition summary Total depth: measured 12208 feet Plugs (measured) true vertical 11343 feet Effective depth: measured 10916 feet Junk (measured) TOC plug @ 10916' true vertical 10055 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 310' 26" Driven/Grouted 310' surtace 439' 18" 540 sx 439' Intermediate 4019' 13-3/8" 2400 sx 4019' 3770' Production 7962' 9-5/8" 1800 sx 7962'. 7280' Liner 4336' 7" 550 sx 12208' 11350' Perforation depth: measured See attachment true vertical Tubing (size, grade, and measured depth) None in the well Packers and SSSV (type and measured depth) None in the well 13. Attachments Description summary of proposal X_ Detailed operations program- _ BOP sketch X_ 14. Estimated date for commencing operation 15. Status of well classification as: June 1, 1995 16. If proposal was verbally approved Oil _ Gas _ Suspended _ Name of approver Date approved Service Injection of non-hazardous oil field wastes 17. I hereby certify that the foregoin i rue and orrect to the best of my knowledge. ~~~ Si ned G. Russell Schmidt'Title Drillin Mana er Date March 31 1995 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug Integrity _ BOP Test Location clearance _ _ Mechanical Integrity Test_ Subsequent form required 10- A roved b the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ~ • Granite Point Platform GPP #44-11 Revised March 31,1995 Objective: Convert well #44-11 from a temporaily suspended shut-in well to a service well for injection and disposal of non-hazardous oil field wastes (Class In associated with drilling, production and workover operations. Also to demonstrate tubing by casing annulus mechanical integrity. Background: This well was originally drilled in 1968 to a depth of 12471', drill stem tests indicated the well was dry- hole and thus it was subsequently abandon and suspended as per the attached schematic. Recently, this year in March, efforts to determine mechanical integrity of the 9-5/8" as well as slickline gauge work was performed to gather data about the present status of the wellbore. Gauge ring runs were only able to work as deep as 4617' wlm, this is explained by the present of 11 ppg drilling mud left in the hole since 1968'. It is believed that the mud has separated and dehydrated to point that water is on top with partially solid mud below. The 9-5/8" casing was pressure tested to 1500 psi at which point the wellhead/tree adapter seal flange leaked, efforts to repair the flange were unsuccessfiil. Also injection into the 13-3/8" x 9-5/8" was attempted, but was stopped once 1300 psi was achieved, a total of 10.75 bbls was placed into the annulus. Workover Procedure: 1. Confirm well is dead, no pressures. Skid rig south to allow access to well through the drill deck. Remove 13-5/8" adapter seal flange. Set BPV as required. Install 13-5/8" 5M riser (CIW btm x flange top), nipple up 13-5/8" double gate with 3-1/2" ram (btm) and blind ram (top). Test BOP per Unocal specifications. 2. RU 3-1/2" elevator to West crane. MU 3-1/2" landing joint, RIH and engage tubing hanger. POOH, recover tubing hanger and single joint of tubing below hanger. 3. RU Dowell coiled tubing unit (1.75"), test BOPS per Unocal specifications and complete Unocal pre job checklist for coiled tubing operations. 4. R1H with 1.75" CT, expect to tag dehydrated mud at 14300', begin washing down and continue to 17950' (depth of desired bridge plug). Note: Review nozzle selection, possible use of bits / underreamers and motors. Centralizer might by necessary to enter top of 7" liner. All fluid returns are to be captured onboard, no discharge into the Inlet is allowed (mud contains 5-7% oil). Make up water for the operations should be Inlet water. 5. Once at 7950', displace the entire wellbore to Inlet water. POOH. 6. MU 9-5/8" casing scraper on coiled tubing, RIH (snub/push) with same to a minimum of 7800', limitation on the amount to push the coil down will be established by Dowell. This step is necessary to assure that the USTT/GR tool can be RIH to evaluate cement and casing conditions. 7. RU Schlumberger wireline. MU USTT/GR tool (cement & casing inspection). RIH to approximately 7800', log up to TOC in 9-5/8" (est. TOC is 14650'), continue to log to surface with casing inspection portion of the tool. • GPP #44-11 Procedure 3/31/95 Page 2 Note: • Transmit (fax) the log to Anchorage office ASAP for further review and evaluation, use fax number 263-7862. Pursue with Schlumberger to pre-program the internal yield for the 9- 5/8" casing strings, this will allow easier interpretation of revised internal yields based on remaining wall thickness. 8. RU gauge ring/junk basket for 7" 29# casing on wireline, verify gauge is larger than a permanent bridge plug OD. RIH with gauge ring to 7950' ETD. POOH. 9. RU 1.75" CT, cement pumper, batch mixer, etc. Install predetermined BHA (BP or nozzle) and R]H to 7950'. M&P a cement balance plug from 7950'-7800' with t9 bbls of 15.8 ppg slurry. Circulate coil clean and POOH. 10. MU 9-5/8" bridge plug on wireline. RIH, set same at (6350'. This step is optional, please discuss the situation with the office prior. 11. Pressure test the 9-5/8" casing to 3500 psi (60% of yield) for 30 minutes, achieve this pressure at 500 psi increments. Monitor all casing annulus for possible communication. Casing Size Yield Collapse N80, 40# 5750 3090 psi N80, 43.5# 6330 3810 J55, 61# 3090 1540 Note: Depending on the evaluation of the cement bond log, the above pressure test will likely be changed to a higher value. 12. Release CTU or move and begin RU of the Dowell Jacking Frame. 13. MU 3-1/2" tubing completion assembly (to be determined); wireline entry guide, tubing tail, profile, 9-5/8" packer, tubing as required and FMC tubing hanger (12" x 3-1/2" "B" with type "H" BPV. R1H with completion tail to (5070', land the tubing as required. Nipple down the BOPE and install the 3-1/8" 5M tree and test same to 5M Inhibit the tubing by casing annulus with Nalco packer fluid, take returns either on the casing annulus or tubing. Pressure up the tubing as required, to actuate and set the packer. 14. RU to the annulus and perform a mechanical integrity test (MIT). The casing must be tested to a surface pressure of 1500 psi or 0.25 psi/ft x TVD depth of packer, or whichever is greater for 30 minutes, if the pressure declines more than 10% in 30 minutes contact the office to discuss. Note: Contact the AOGCC within 24 hours to witness the MIT. Additionally, RU two pin recorders (permanent installation), one to the 13-3/8" x 9-5/8" annulus and the other to the 9-5/8" x 3-1/2" annulus. 15. Rig down the jacking frame. 16. RU Schlumberger to perforate the intervals for injection, RIH with Enerjet 2.5" perforating gun assembly as required. Perforate the intervals as direct. • • GPP #44-11 Procedure 3/31/95 Page 3 17. RU to establish injection (rates and pressures) to satisfy solids/Iiquid injection requirements. 18. Secure well, RDMO. Total time required t 10 days Filename: Granite\OBMlproc001.doc • • J 26' Structural 310' @ 18' Surface @439' 71 #, Grd-B, Vecto DV Collar @2227' 13/8• Intermediffie @4019' 61 #, J-55, BTC Est. TOC @ 4657' roar®~r a~s~e' ®~aez' ~o~a.s~ weo. arc srd No+ ane•~sxss•; ~.ss Fisrss-err! cn,we Hq ~oa~a•»o,s• i»sa-msr wao soz i ~aaa-iiz+s• wn i ~zrs••»anw rn eP ®++~o' ~ uoa•»+o~• wao soz »szr•»e~a r.n i ~aer•~nos wn ar @ ~~~s• r zcf tsoxi,. ®~szas• Granfte Point Fleld; Well #44-11; API 50-733-20059; ADL 18761 Leg 1, Conductor 2, t® elev=105' Spud 7-8-68, Last WO 10-7-68, Stffius: Shut-in dry well UNOCAL ENERGY RESOURCES ALASKA DRAWN: CLL DATE: 3-16-95 FILE: GP4411A.dtw • • ~~' ~ 26" Structural 310' 18" Surface @439' 71 #, Grd-B, Vetco Completion Equipment: 1) 3-1/2" 9.2# L80 SCBTC 2) Packer @ 5030' 3) "X" Nipple @ 5040' 4) Wireline entry guide @5070' DV Collar @2227 13-3/8" Intermediate @ 4019' 61 #, J-55, ??? Est. TOC @ 4657' Potential Injection Intervals (DIL); 5120'-5210'(90 5255'-5315' (60~ 5320'-5370'(50 5420'-5485' (65~ s~i~o=-"v8v' 5955'-6020' (65~ 6125'-6285' (160 BP @6350' Cement Plug 7800'-7950' TOL r ~ 7e7r Max Dev. = 28.3 deg @5600' Y-5/8' Q 7982' 40-49.Sf Na0, LTC 8b (40# Fl78'3253'; 43.5~F F/5259-7982 CanaK Plug 10918'•i 1915' 11150'-11151' WSO SOZ 11230'•11245'Pa'1 11275'-11290'PeA BP Q 11330' 11400'-11401' W30 S~Z 11520'•11810' PwT 11883'-11705'PsA BP ~ 12148' r z9,r Leo x-r,. ~ 122oe' Granite Point Field; Well #44-11; API 50-733-20059; ADL 18761 Leg 1, Conductor 2, KB elev=105' DRAWN: CLL Proposed Conversion to Injection SATE: 3-16-s5 UNOCAL ENERGY RESOURCES ALASKA FILE: GP44116.drw • • Flanged to Coiled Tubing BOPE or Wireline lubricator ~- ~ BLIND RAMS 13-5/8" 5000 PSI PIPE RAMS 13-5/8" 5000 PSI RISER 13-5/8" 5000 PSI Flanged to 13-5/8" "B" section of wellhead Granite Poirrt Field; Weil #44-11; API 50-733-20059; ADL 18761 Leg 1, Conductor 2, KB elev=105' DRAWN: CLL Proposed ROPE for #44-11 I DATE: 3-29-95 UNOCAL ENERGY RESOURCES ALASKA I FILE: BOPE4411.drw • • Appendix B • March 31, 1995 To: Alice Bullington From: Dan Ind /lC'Bir. GEOLOGIC REPORT OIL FIELD WASTE DISPOSAL MOBIL WELL # 44-11 GRANITE POINT FIELD INTRODUCTION This report details the geology of the area surrounding the Mobil well # 44-11 at the Granite Point Platform and provides the geologic evidence in support of UNOCAL's application for injection of water and other oil field waste into the Upper Tyonek D Sand. SUBJECT WELL An area map (Exhibit 1) shows the location of well # 44-11 (red) which deviates to the NW from a surface location at the Granite Point Platform. The black circled "X° marks the location of the proposed point of injection into the U. Tyonek D Sand. The yellow circle centered at this injection point highlights the area within one-quarter mile. The penetration points of other wells encountering this sand are highlighted with a smaller black "X". No wells in the Granite Point Field have ever been pertorated in this zone. Also shown on this map are the lines of cross- section (green) displayed in Exhibits 2 and 3. STRATIGRAPHY Lower Tyonek The primary oil bearing reservoirs in the Granite Point Field are within the sandstones and conglomerates of the Lower Tyonek Formation. The L. Tyonek is series of nine sand packages interbedded with siltstones, mudstones, and coals. The shallowest oil production is from the second L. Tyonek sand. This sand is 20' - 40' thick and is encountered at depths ranging from 7800' to 10,000' sub-sea in the Granite Point Field. Upper Tyonek The U. Tyonek Formation is similar in lithology to the L. Tyonek. This interval grades upward from abundant sandstones near the base to sparse sandstones in the upper part. Very few of the shallower sandstones (< 6000 are laterally continuous over a large area. The D Sand is one of the more continuous sandstones. The proposed 20' of pertorations are at a depth of 5460' to 5480' measured depth (-4947 to -4965 sub-sea) in the lowest lobe of the D Sand (Figure 2). It was chosen for injection because of 400' of relatively impermeable rock below and 1400' of relatively impermeable rock above (Exhibits 2 & 3). These impermeable zones contain interbedded siltstones, mudstone, coals, and lenticular sandstones. The U. Tyonek A Sand is within the upper impermeable zone and is probably continuous in the area of the injection point. This thin zone is a silty sandstone and is the shallowest mapped zone in the area. The Frac Model produced by George Buck and Marty Hrachovy indicates that any fractures produced by the injected fluids could propagate above the A Sand but not beyond the impermeable zones above the A Sand or below the D Sand. There are no hydrocarbon-bearing reservoirs in the U. Tyonek. The U. Tyonek Formation continues up to the base of the Beluga Formation (approximately - 2000' sub-sea) which is beyond the scope of this report. • WATER ANALYSIS • The U. Tyonek D Sand has never been tested or produced in Granite Point Field which precluded any standard laboratory analysis being done on the formation water. Analysis of field electric logs was used to estimate the total dissolved solids (TDS) within the D sand. The method followed in the analysis was that established in the U.S. Environmental Protection Agency publication entitled Survev of Methods to Determine Total Dissolved Solids Concentrations. The #44-11 well logs or any of the other 1960's vintage logs from nearby wells could not be used to conduct the analysis by either of the accepted methods. These wells were drilled using saltwater based drilling muds which yield very high TDS estimates using the SP method. The older logs also lack quality porosity logs over this shallow interval to use the Resistivity -Porosity Method. The nearest wells with reliable logging suites were Unocal wells #50 and #51 drilled and logged in 1992. They both penetrate the D Sand approximately 1500 feet to the SE of the 44-11 well penetration. The quality of the SP log in these wells was questionable so the Resistivity - Porosity Method was used to conduct the analyses. A TDS estimate was made on both the U. Tyonek A and D Sands in these wells. The A Sand is very clay rich and may not yield the best results. The results are included because any fractures that might be produced by injected fluids could possibly reach this zone. The log values used in the analyses were chosen over intervals of the sand where hole condition was determined (from caliper and tension logs) to produce the most accurate log values. A summary of the results and depths analyzed are found in Table 1. The D Sand shows a range of 3291 to 6847 ppm TDS. The average of the six values is 4672 ppm TDS. The A Sand values, which are probably somewhat high due to the shaley nature of the sand, range from 6852 to 9742 ppm TDS. The average of the four values is 8442 ppm TDS. The log headers and analyzed log intervals can be found in Figures 2 through 13. A summary of the methods and formulas used to produce the results in Table 1 can be found in Table 2. It appears from the log analysis that U. Tyonek D Sand has a high enough salinity to be used as zone for injection of oil field waste fluids. Also, it appears that the A Sand is also a salt water bearing zone should fractures propagate this high in the stratigraphic section. TABLE 1 MEASURED SUBSEA NEUT. DEN. AVG. DEPTH DEPTH POR. POR. POR. Ro We-l #50 U. Tyonek A Sand 4372 4225 24 18 21 10 4385 4238 22 19 20.5 10 U. Tyonek D Sand 5124 4956 25 19 22 10 5144 4976 26 24 25 15 5164 4995 25 22 23.5 13 Well #51 U. Tyonek A Sand 4382 4394 U. Tyonek D Sand 5054 5079 5113 F Rw Tf Rw 75 SALINITY 18.4 0.544 93.3 0.666 8374 19.3 0.519 93.5 0.636 8799 16.7 0.598 103.4 0.805 6847 13.0 1.157 103.7 1.563 3391 14.7 0.886 103.9 1.200 4484 4272 29.5 16.5 23 10 15.3 0.653 94.0 0.804 6852 4284 30 15 22.5 7.5 16.0 0.469 94.1 0.578 9742 4943 29 18.5 23.75 9 14.4 0.627 103.2 0.843 6519 4968 31 23.5 27.25 13 10.9 1.192 103.6 1.608 3291 5002 32.5 22.5 27.5 12 10.7 1.120 104.0 1.518 3497 • • Table 2 Thermal Gradient Formula: TG = (Tmax -MST) / (Depth Subsea / 100) • Tmax = Maximum recorded temperature from log header MST = Mean Surtace Temperature for Cook Inlet (35° F) Depth Subsea =Meas. depth of Tmax converted to subsea depth Note: Data from the #50 well yield a TG of 1.36 to a depth of -9691 subsea. Data from the #51 well yield a TG of 1.39 to a depth of -9256 subsea. A TG of 1.38 was used in the calculations Formation Factor: F = 0.81 / ~ (Tixier Formula) ~ =porosity (taken from the average of the density and neutron log porosity). Resistivity of 100°k Water Saturated Formation: Ro = Rt (deep induction R value through analyzed zone assumed to be 100% water). Resistivity of Formation Water: Rw=Ro/F Formation Temperature: Tr = (Depth subsea / 100) x TG Resistivity of Formation Water at 75° F: Rw@75 = Rw ((Tf + 6.77) / 81.77) Salinity (ppm at 75°F): Salinity = 10" x = 3.562 -log (Rw~75 - 0.0123) / .955 • • 44-11 SPnrm FE MD ET TVDSS IL D 0 0 rn 0 0 i 0 0 0 O 0 m `" o i 0 ~.: x;~< ~.< O °~" o is ` a. ~ O ~ O ~ >;€~;~: ~ I `~~` ` :i``Y:`; '~ ii:yiiF .'S's:' O O O O :'~~.\ . .... ;.;r;;;; pro sed :::.:.:: : < pe s O O .O ~ O ~ v i 0 0 co '~ O o .., Fig ure 1. Pr opo sed perforations , U. Tyo nek D Sa i nd, Weil # 44-11 • • ;hj .' "-r :' ~_ I 1.. . ~: ti ~r}; 't ;I ,i I~ ii ii ;~ ,. -. ~~. ~i - .. , . _ _ - PHASOR DUAL INDUCTION .- .• _ 5" ~ . COMPANY: WELL: FIELD: LINTY: STATE: UNOCAL GRANITE POINT #50 GRANITE POINT KENAI ~~a ~~, _ ALASKA Location: COND'#3-11 `2386' S & 1372'. E .API Serial no: 50-733-20434 FROM NW CORNER ~ SEC: 13 IWN: 10N RNG; 1 ~W Permanent Datum: , M LLW ;Elev.: 0.0 Elev.: K. B. 109.1(1 Lo Measured From: KB 109.1 ABOVE PERM. DATUM D.F. Drilli Measured From: 'KB G.L Date ~ OtJUN-92 23JUN-92 10JUL-92 Run No. ONE TWO THREE Depth Driller 3830.0 10081.0 12145.0 Dept Logger 3834.0 10052.0 12100.0 _ Btm. Log Interval 3828.0 10046.0 12094.0 _ ,_ Top Log Interval 981:0 1500.0 10048.0 Casing-{hiller 485%8" @ 982.0 13 3/8" @ 381 ZO 9518" @ 10063A Casing-Logger 981.0 3812.0_ 10048.0. ~ _ Bit Size ~ 17 1!2" @ 3830.0 12 1/4" @ 10081.0 8 1/2" @ 12145.0 . Type Fluid in Hole GELNYATER _ PHPA _ _ PHPA _ ~ ~ Dens. Visc. 10.00 LBIG 38 9.30 ,LB1G _ f 48 13.30 LB/G 64 pH Fluid Loss 7.7 19 9.7 5.4 9.3 4 2 Source of Sample Rm @ Meas: Temp. CIRC 2.52 @ 67°F CIRC 2.24 @ 78°F CIRC __ 222 @ 78°F _ Rmf r~.Meas. Temp. Rmc @ Meas. Temp,. 2.11 La767°F 67°F 2.80T@ 2.21 @ 78°F 2.78 @ 78°F t.57 @ 78°F 3.24 @ 78°F Source:Rmf • Rmc _ M M M M M M_. Rm @ BHT= Rmf @ BHT -_ - - . _-Circulation topped _ - - Logger on Bottom Max. Rec.7emp.. SEE LOG 126°F SEE LOG 167°F ~ SEE LOG 184°F - - . Equip. _ Location: 210 I~NAI 210 I~NAI 210- ~N ~- _-- 'Recorded_Bp..;:. HAUGAARD: HAUGAARD HAUGAARD ,, -. Witttessed B > STEWART STEWART STEWART _ i -; Figure 2. Header, induction log ,well #50 .. ' r~.... ;f, ~.r~. ,. _.. Tyonek A Sand ~- _ _t. ;Figure 3. Induction log, U. Tyonek A Sand, well #50 i ` iuwr 0.0 10, 000 I , ------------------------•--....._..-I-- -hiMM~---------- .20000 2000.0 -___-- SPj-MVO------ SFLUGHMM _ '.50.0 50.000 .20000 F 2000.0 GRGAPI ------------- IDPH-LOHMM~_--_--_- __ - 100.00 20000 .2000.0 - - - - --- -_. _.___T _.. Tyonek D Sand 5100 _; ~ .,~ 5200 ~ ~ ----{--;-;--I- ~-- ~~ .~ ~., - ~ , ~~ ~ i, Figure 4. Induction log, U. Tyonek D Sand, well #50 • • i DENSITY-NEUTRON POROSITY 5" I I COMPANY: WELL: FIELD: COUNTY: STATE: UNOCAL GRANITE POINT #50 GRANITE POINT KENAI ~~ c~ -= ~ ~~~,~y(pJ)q ALASKA ~ ~ Location: COND #3-11 2386' S & 1372' E ~~ FRO NW CORNER API Serial no: 50-733-20434 SEC: 13 TWN: 10N RNG: 12VY1 Permanent Datum: MLLW ;Elev.: 0.0 Elev.:K_B. __ __1.09.10 Lo~_Measured From: KB 109.1 ABOVE PERM _DATUM _ _______ D.F. ____ Driflin Measured From: KB G.L Date 23JUN-92 10JUL-92 _ --- - ___T ___ - _-______, ~ Run No. TWO - -- - - THREE - - ~ --- I ---- - Depth Driller 10081.0 12145.0 Depth Logger 10052.0 - 12106.0 _--- -- ----- ------_ -._ Btm. Log Interval Top Log Interval 10046.0 1500.0 12104.0 10048.0 __ ___ _ _____ __ __ . Casing-Driller 13 3/8" @ 3817.0 - 63.0 9 5i8" @ 100 -Casing-Logger - -3812.0 --- _ 10048.0 _-- _ _---- - _-- --_-_-- , - - - Bit Size -- 12 1 /4" @ 10081.0 ---- 8 1!2" @ 12145.0 ---- -- --- --- ------ ~ --- i --- - - ----- Type Fluid in Hole. PHPA PHPA _ -- ---- L __ _ ____-__ T -- -- - Dens. Visc. ------ 9.30 LB!G T 48 13.30 LB/G ~ 64 - ----.... - - - --- _ - -- - - ~__,__. ___ - ----- - - pH Fluid Loss -- 9.7 5.4 r 9.3 _4.2 I Source of Sample CIRC CIRC i _ - Rm @Meas. Temp. -_ Meas. Temp. Rmf @ 2.24 @ 78°F 2.21 @ 78°F 2.22 @ 78°F t_57 @ 78°F -______ __-_ -_____ _ _ Rmc @Meas. Temp. -- - 2 78 ~.~ 78°F --- 3.24 @ 78°F ------ _._. ' Source:Rmf Rmc ----- ~-- M M -r- M ~ M ~ --- Rm @ BHT Rmf @ BHT ' Circulation Stopped __-__-- .- - __-- --- Logger on Bottom - _-- - SEE L_OG SEE_LOG - -_` _ __ _ __ I Max. Rec. Temp_ _ Equip. Location: _ 167°F __ 210 - ___=KENA1 _ 185°F 210 ~I~NAI _ _ ____ ~ __ ~. -_ Recorded By HAUGAAAD HAUGA_ARO ___ _ __ __ Witnessed B STEWART STEWART Figure 5. Header, Density-Neutron log ,well #50 ----- HTENSLBF Z--------------- 10000 0.0 ----- CALIL1------ 10.000 20.000 GR GAPI ~ - - - PEF - - ---------------DRHO(G/C3)---------:--- 0.0 ~ .45000 -.0500 --------------NPHI(VN1------------- .45000 -.1500 DPHI(VN) 0.0 100.00 .45000 '.1500 ---_ I r` - I ~~- - 1 - ~ 'I - I-~'-~ - I I _ ' 1 I C I I --~- - ~: i I _ I I ` I ~ ~ -I- --1- I t- ~ ~ 1 I I -~~ I I -~ I ~ _ ~__ __ I ~ I ~---- + ~ ,T I 43 00 . I ~ I r ,j ~ I ` I - ~----~-} ~i ~ -~ ' ' I I ~ I I - I _ _ 1- f--- ~- ~ I I I I I ~ ' I I I ~ __ I I I ~ I I 1 ` ~- I I U T o nek A San d ~ . y I ; ~J \ I r i .~ r I I I - I I - ;- ` I I I _ I , I •, i i ~ - I ~T I I --- 't ~ - -- ~ r w- I 1 i I _ ~ ~ ~ -` --- -' '- - ' - -- _--_ _~ ~ ~I . _._ 1 _ _.. .--'- -_ _ _ .L.~ -•--r~- I i .-'_-_ ---~- i I - -- I I ~ 7 r h ~ I ' I TT- I ~ I I - I I _. I { 1 1 I I ` ` !~ -t-. -" Figure 6. Density-Neutron log, U. Tyonek A Sand, well #50.~ =-~------------- HTENjLBFZ------------- - - - - PEF - --------DRHO~G/C3)-------- ;10000. 0.0 ~ 0.0 .45000 - - - - - 0500 ------ CALILN1------ --------------NPHI(VN~ ------------- ;10.000 20.000 .45000 -.1500 GR GAPI DPHINN ) ~• 0.0 100.00 .45000 -.1500 - _ _ - _- ' - - --- ' ;~r' ---~-+ ~_ -t-- I I Tyonek D Sand 5100 I ~, I 1 i i i i i -__.. .._--4---..~_~, . __-_ ~. _ ___i ___. i i "-; ;~ i , I I. t I I ~1 I I ,- 5200 ti i i I ' 1 ~- I ~ -~ i I i I i I i .r r i I --r ~ ' a ~ ~~ I I -+ I _ I ~ 1 I/ i -- ~ i - ~ i I _.._ l.. __~_ __. ._____ --_ ___ :3- y .. --- - -- - "-- - --- -- ---}--- r ~ --+-~----- ~- -- -- I -Ir- - .i -*-- ~ --~-J- - - ~--- i ~ .l I ~ _~-_ ~ rt ~ Nei ~ 1 I - i -~--- -~-- ~-~ I -~-- i i ~ I -t N- ~ 1 ~ 1 - i -- 1 i _ I I i 1 ~ ~ _. i ~ I Figure 7. Density-Neutron log, U. Tyonek D Sand, well #50 • • i PHASOR INDUCTION-SFL .- .- 5" COMPANY: UNOCAL UVFI 1 (.Q A 1-IITC ~l11wIT .usi r FIELD: COUNTY: STATE: GRANITE POINT KENAI ALASKA ~ : ~~^ a~~~~ h ~~ °w Location: 2385' FNL & 1374' FWL Yw~~~' APl Serial no: 50-733-20436 SEC: 13 TWN: 10N RNG: 12W Permanent Datum: MSL ;Elev.: 0.0 Elev.: K. B. 109. 1 L Measured From: KB 109.1 ABOVE PERM. DATUM __ _ _ D.F. Drilli Measured From: KB __ G.L Date 21,AUG-92 043EP-92 Run No. ONE TWO - - - Deplh,Driller 9782.0 11839.0 - - - Depth Logger 0.0 11787.0 Btrn. Log Interval 9741.0 11781.0 __~ Top Log Interval 4017.0 8400.0 - i Casing-Driller _ _-_ 13 3/8" @ 4017.0 95/8" @ 9762.0 _ Cesm$-logger --- 4017.0 9748:0 _ Bit SIZE 12 114" @ 9782.0 8 1/2" @ 11839.0 _._ Type Fluid in Hole FRESH GEL MUD EZ-MUD DP Dens. Visc _ 9.40 LBlG 47.0 S 8.70 LB/G 48.0 S pH _ Fluid Loss _ _ _ 9.5 5.0 C3 9.4 4.4 C3 Sourc~ofSemple FLOWLINE FLOW LINE Rm_~a; Meas Temp._ 2.730 @ 84° F 1.740 @ 78° F Rmt (ti? Meas Temp_ 2.590 @ 62° F 1.930 @ 78° F ~ --~ Rmc ~£ Meas. Temp. _ 2.530 @ 58° F 2.460 @ 78° F -- Sarca,Rmf Rmc MEAS MEAS MEAS MEAS Rm C?% BHT Rmf (i~ BHT 1.453 164° F .836 170° F CMCUI~tion Stopped 1000 21-AUG-92 0630 O4-SEP-92 Logger on Bottom SEE LOG SEE LOG Max. Rec. Temp. _ 164° F 170° F -1 Equip Location: _ 210 lCL-NAI 210 I~NAI --_ -- Recorded By MCCROSSAN CRYER _ 4Vi~essed B STEWART STEWART Figure 8. Header, Induction log, well #51 i civ_~~~gr ~ 0.0 10000. GR(GAPq 0.0 100.00 --- SP-LL---- -so.oo 20.000 ______HTEN(LB~______ Tyonek A Sand 4300 4400 ~~ .20000 2000.0 .20000 2000.0 _____________ IDPHlOHMM~_____ ..- Figure 9. Induction log, U. Tyonek A Sand, well #51 --------=--- --- 'tNS~~tjr -__ ------- ~J.O 10000.- - GR GAPI . '0.0 100.00 -eo.oo I 20.000 !, {----- -HTENtLB~------ ~U. Tyonek D Sand STCU(OHMM .20000 2000.0 •---•------------------------------ IMPH(OH MMZ-------------- -------------------- .20000 2000.0 ------------- IDPHLOHMML-------- .20000 -----. ,, I~ i I -. T i .w Figure 10. Induction log, U. Tyonek D Sand, well # 51 ' _ - • • .- .- COMPENSATED NEUTRON LITHODENSITY LOG. (5" ) COMPANY: UNOCAL WELL: GRANITE POINT #51 FIELD: GRANITE POINT COUNTY: KENAI STATE: ALASKA Location: 2385' FNL & 1374' FWL API Serial no: 50-733-20436 SEC: 13 TV1/N: 10N RNG: 12VV Permanent Datum: MSL ;Elev.: 0.0 Ele_v_.:K_._B. _ __1__0___9.1_ Log Measured From:- KB 109.1 ABOVE PERM. DATUM D.F. Drillin Measured From: KB G.L Date 21-AUG-92 04-SEP-92 Run No. ONE TWO Depth Driller Depth Logger 9782 0 -» 0.0 c, ~ 1838 OT. - - 11787 0 , - -- ---- 13trn. Log Interval --- -- - 9668.0 .. --- ---- 11724.0 _ - Top Log Interval 7 4017.0 -~ ,,, -- 9$Qq p - -- Casmg_Driller _ _. _ -_ 13 3!8" @ 4017-0 - 9~,/~'762.0 Casing-Logger 4017.0 9748.0 &t ::ize 12 1 '4" ril 9782.0 8 f; Z' @ 1 t 839.0 Tvt~e Fluid in Hole FRESH GEL MUD EZ-MUD DP Den::. Visc. 9.40 LB~G 47.0 S ~ 8 70 LB/G 48 0 S __ 1- pt ~ Fluid Loss 9.5 5 0 C3 9 4 4 4 C3 ~ S"~.+rce of Sample FLOWLINE FLOWLINE Rm rc- Meas_ Temp= 2.730 ~~ 84° F 1.740 cti 78° F Rmf -gig Meas. Temp 2.590 ,ci: 62° F 1.930 @ 78° F Rmc Ri Meas. Temp 2.530 +;,~ 58° F 2.460 @ 78° F Source Rmf Rmc MEAS 1 MEAS MEAS MEAS Rm uc~ BHT Rmf (a7 BHT 1.453 1 164° F 836 170° F Cx<<.dalion Stopped 1000 21-AUG-92 0630 04SEP-92 L~,yyer on Bottom SEE LOG SEE LOG Max Rec. Temp t 64° F 170° F Equ+p- Location 270 KENAI -_..-- 210 ,KENAI -- 1 Re.~c~rded By MCCROSSAN _. CRYER Wrtnessed By STEWART STEWART _ _ -__-- Figure 11. Header, Neutron-Lithodensity log, well #51 BS I N 6.0000 16.000 -------------- TENS~LBF } --------------- 0.0 10000. GR GAPI i • PEF DRHO(G /C 3) 0.0 100.00 --------------- CALIiIN-~ ---------------- 6.0000 16,D00 ----,HTENLBFI-----_ _ _ _ _ _ _ _______ ~ _ _ _I_______________ 0.0 10.000 -.2500 .25000 - - - - - - - - - - - - - - NPHI(VN~ - - - - - - - - - - - - - .30000 -.1000 DPHI(VN) 0.0 5000.0 .30000 -,1000 -_ -'~- .,. - _ ~_ :~~~ - -- -~~ 4300 r--- _ --- ~ - a _ --- _-. r ~ .~, C - -.. - -_- i I -- ~ - ,4 ...~ 5~ T onek A Sand -- ~ ' y - - ~ - - . - - ~ \ _S --~---_ ._ - _ -- ~ _ - -- - - - - "~ - ._~._ . i-_ .- -_,. ~ _ ~ --, I ~.cooo 1s.ooo -------------- TENS~LBF) ~-------------- M ~ • 0 10000. GR GAPI ` _ _ _ PEF _ _ ~ ________________DRHO(G/C3)-__--_____ ~ 100.00 0.0 10.000 -.2500 25000 --------------- CALISIN-~ ---------------- - - - - - - - - - - - - - - NPHI(VN1 - - - - - - - - - - - - - :.0000 16.000 .30000 -.1000 _-----HTEN(LB~------ DPHIVN 5000.0 .30000 -.1000 A ----T i ..- ---- _~-- ' , - Tyonek DSand -~ • • Appendix C • • I I I I I I I ITIINTRI~W1 I ITIINTRII I 16 I 15 I 14 I 13 I 18 I 17 I 16 I 15 I I I I I I I I DANCO--100% c?1 c'~ ! 23 I 24 19 ~-)~~.#'' ''? ~20 1646.6® AQ2 - _ ~A ITE _.PT^ l i~G.' 3-31rt98 _ _ _ _ _ ADL-374061 - I I I - ~ DANC^I-100% ~; (\ 0 AC 28 27 I 26 I ,f 30~ 29 28 I 27 P ARC0=50% ! - ~ j~ AI)L- .~~7~5d r ! ~, MARATHON ~ ~ ~~~~.A ~ ~ ~~ ~. I 5oz UN SAL- 10 ~ 7 I 33 3a I 35 I 3 ~ I I 1`, 32 3256 AC4 I 13070 ACI ~ ~ 3-3~-98 _ HBP BR~~_ ADL- 74062 I a ~ ~~`'~~" `~ 2% j l 6 ~~ 5 PH4LLI~S-40% I ~ ARCO ~±::;'t3IL l~ y~ I 100 /. ` ' ,=~ % r ~-Q ~ ~~ - - - - - -~- - - - I ~ 10 11 I/ ]c ~ ;[~ j4 ,{7 ~'C~ 8 4480 i AC 10 I ;~' I 2-291-00 s~Q s - - - ` - ' ` '~`~'' ADL-3 1038 1 d Mile Ra~iiu #~rea -~ 4~i 11 In action Point A C ^ - 6 0 IADLHBP585 ~ 1 PHILLIPS-4d% I 16 15 ~ 13 ~~ '8 17 I 16 I L I ,~ QRANITE PT. I 1 ~~ - ~ - -~ - _ _,~_ _ _ _ ~ aN-+~1~~ aR~o_bo% PHILLIPS-~0% 2288 A 22 ,%`f(23 ~ 500 /A~' 19 z~20~ AC21 22 3-3 -98 I BP ~ 2-2Q-00 3e.o nc ADL- 74041 -18 ti ] ADL- 81039 an ~ e~a t"'~1+:~(=~~~-, ! .ii;• ~~ ~ !"!;~,;~t_'A~T.~- 100' ARC -60% ARC^ 60% 2B I 27 26 _: PHoLLIaS-40% PH2a LI~S-40%~ s --- ` _2 M LEA- ---- I --- ----{-..----~ -~ ~- ~~6b Ai' -~-~,~->>i> ~~~. 253 AC 1 5120 I AC 33 I 34 35 I 36 31 ~ 32 I 33 I 3a ~ 3~- ~~ 3-3 ~ -98 2-2~-00 I 2-29x00 ;~ ~ ~ rt:?L-_ fir' ~~ ADL-3,81040 I ADL-3$1214 ~ • • TO THE ALASKA OIL AND GA5 CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of Application ) For Well Conversion for Union Oil ) Company of California for Application ) of a Class II Disposal Well as Required ) by 20 AAC 25.252 ) STATE OF ALASKA ) ss. THIRD JUDICIAL DISTRICT ) Alice Z.R. Bullington, being first duly sworn, upon oath, disposes and states as follows: My name is Alice Z.R. Bullington. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am an Environmental Scientist for the well operator, Union Oil Company of California (UNOCAL). Pursuant to 20 AAC 25.252(c), UNOCAL, the well operator, prepared an Application For Sundry Approvals. proposing to convert anon-producing well into a Class II fluids disposal well. A copy of this application is attached. 4. On Apri16, 1995, pursuant to 20 AAC 25.252(c), UNOCAL sent a copy of said application registered mail to the last known address of each owner and operator within aone-quarter mile radius of GP 44-11 surface location and has notified the appropriate departments within UNOCAL. Subscribed and sworn to this 6th day of April, 1995. ~~ _ Alice Z.R. Bulkin STATE OF ALASKA ) ss. THIRD JUDICIAL DISTRICT ) The foregoing instrument was acknowledge before me this 6th day of April, 1995 by Alice Z.R. Bullington. _ ~~~~~~G.~„ KIyLG/¢i Notary Public. ate of Alaska 2p:'. ' :~i<~~y My Commission Expires ~Z ' ~ 9 s* NOTARY ~''UBLIC ' ~ My Canmtseion >~ln« 'i,~~9jF a.....`PS~\`~~~~ ooammber8, t998 De.._ F A _...~~~ A. BullingtF~n9 p ~ ~ ~ 5 219 Certified Mail Receipt No Insurance Coverage Provided *• Do not use for International Mail IRPP RP.VP.rSP.I ^' i$~ SENDER: • Complete items 1 andlor 2 for additional services. & b d 4 ` I also wish to deceive ~Itb #pIIOWinB Services IfOr en eXtrB ~ ~ p . a • Complete items 3, an . • Print your name and address on the reverse of this form so that we can o f@8~C ~' i o > u. return this card to y • Attach this form to the front of the mailpiece, or on the back if space 1. ^ Addressee's Address ;i ~ ~ does not permit. • Write "Return Receipt Requested" on the mailpiece bebw tha article number. 2, ^ Restricted belivery ~S ~ • The Return Receipt will show to whom the article wes delivered and the dete ` COns41t ostmaster foi• fee. ~ C I c delivered. 3. Article Addressed to: 4a. Art icle Number , C r ~ ~ P 9f15 335 219 s~ i ~~ ~ NORM SMITH 4b. Service Type ^ Regi~terBd ^ Insured I ~ MOBIL CORPORATION ~ Certified ^ COD . H W 12450 GREENSPOINT DR ^ Express Mail ^ Eietum,,Receipt for ` ~ '~ HOUSTON TX 77060-1991 rc~ is~ M $ ~ i 7. Date of Delivery a ~ o~C Signature (Addressee) 5 8. Addresseei'fs Address (Only if requested i ~ W . and fee is paid) N r-I .--I N W 1, ~ 6. Signature (Agent) ~ ~ ~ ~ PS Form 1, December 1991 ~ us.G.P.o.:tesz-ao~-sao .DOMESTIC RETURN RECEIPT + _. i C c t C Fc Sent to Norm Smith Street & No. Mobil Cor oration P.O., State & ZIP Code 12450 Greenspoint Dr. Certified Fee Special Delivery Fee Restricted Delivery Fee Return Receipt Showing ~ to Whom 8 Date Delivered Relurn Receipt Showing to Whom, Date, & Address of Delivery i ~ TOTAL Postage ~ & Fees ~ Postmark or Date 5 L • •. • - •.- ... P 9QS ?~~ 219 • • Appendix D • • M~Dr~ing fluids.., MUD PROPERTIES AND CONCENTRATIONS OF A TYPICAL COOK INLET OIL BASED MUD MUD WEIGHT MUD VIS PV YP FLUID LOSS (HPHT) OIL/WATER RATIO CI" ELEC STABILITY 9 - 12 PPG 40 - 100 SEC/QT 20 - 40 8-20 5.0 70/30 35,000 300 - 400 PRQDUCT NAME GENERIC NAME CONCENTRATION /BBL M-I BAR Barite 0 - 200 LOWATE Calc. Carbonate 0 - 100 VG-69 Organophylic Clay 2 - 8 VERSACOAT Wetting Agent 0 - 3 VERSAMUL Emulsifier 2 - 4 VERSAWET Wetting Agent 0 - 2 VERSA HRP Polymer 0 - 1 LIME Lime 4 - 6 CaCl2 BRINE Calcium Chloride .28 bbl LVT 200/MAPCO 200 Base Oil .60 bbl A11377 ENVIRONMENTALLY INVOLVED NOTE: SEE REVERSE SIDE FOR LIABILITY CLAUSE • • THIS St„-.,. . nn j .,. AC>V."° ,...'~, ~.._ . ., _. _..__ _ a m DE` a~ ~F ANY ANC) ACKt ;; ~NTC7l OE ThiE WELL, T _ 1 __ t ^~LSO. TNE62E ARC CJHI/IC>USLY ,y, _ .., ~~,.,,,,,, ,- } i -! CAN HAVE M1iC~ KNOtNIEC~CE F "C} ~ R HlCN T ~ NOT AN FC3 E, M-I SHALC NOT BE LEABLE Fs~R THE EAIIURE QE AI~~Y E~lJIPC1(ENT T ~ Pf VUF OR THE FAILURE TO OBTAIN ANY PARTICULAR RESULTS FROM CAR(°....C" P TY C~ECEIVING 1T. FURTHERMC7RE, THE OWNER ANC3 C7RERAT{JR s C JNTRACTC~R, IN CC"°ISfC7E12ATlON OF THE RECOMt~EN{~ATIC?NS CONT, 3 !C7CRA~1, ACIaEE TO ~~ ~' ANC} SAVE -I H ,RL FROG ALL CLAD" t° aCE C u - i' TC3 P'' ,, .., C7R PRC7PECZTY, Int.r ~:, ru+11.lr Llr,n~rn , SUBS" "~ ° - ORi ,9URYTOTHElNEI.LOF Lf ,+ . UPON TH15 PRCJCRAt~, UNLE ~ w ! ~ `~ C ~ i= CAUSEL C - VsIILi L ~riiSC:ONE~UCT t7R GRC?SS Ntc~t.tc~i~v u .~r n~i-!. • • Appendix E • Memorandum i UNOCAL~6 03/31 /95 To: Alice Bullington From: George Buck ~f ~1~'' ~~ Marty Hrachovy FRAC MODELING OF CUTTINGS SLURRY DISPOSAL IN GRANITE POINT WELL # 44-11 A cuttings disposal well has been proposed for the Upper Tyonek formation in the Granite Point Field. The injection will be down tubing into a perforated interval 4947'-4965' TVDSS, 5460' - 5480' MD. As the cuttings slurry injection proceeds, the fracture will grow in both length and in height. The purpose of this work is to ensure that the fracture will not endanger hydrocarbon bearing sands, other wells, or extend to the Inlet floor. Base Case Estimate: 200,000 Bbl Cuttings Sluny and Flush Water. This is very conservative as the estimated volume for this program is 105,000 Bbls. The following details the modeling approach, assumptions, and simulator inputs. The modeling is conservative, i.e. it should over predict rather than under predict frac height. Unless there was data to support a given input or assumption, in general I made aworst-case assumption. The base case is my best estimate of frac growth, given the available data. The base case considers the following: • Perforations at 4947' - 4965' TVDSS. • A 2 barrel per minute average pump rate 24 hours /day. • Vertical frac growth as opposed to horizontal or angled. • Radial ("penny") frac shape. • Moderate leakoff coefficient of 0.00150 ft per sgrt min in sandstone and 0.00075 in siltstone • Low Young's Modulus (low rock stiffness) 0.5 a-6 in sandstone and 0.3 a-6 in siltstone. • Slurry acts as a solids-free fluid, has as a fluid carrying solids, therefore solids cannot bridge off at the frac growth tip. • • The formations placed into the model are assumed by the model to be horizontal and were input as follows: 0' - 1000' Sandstone 1000' - 3000' Siltstone 3000' - 4060' Silstone/Mudstone 4060' - 4100' Sandstone 4100' - 4775' Siltstone 4775' - 4960' Sandstone 4970' - 5520' Siltstone 5670' - 6300' Sandstone 6300' - 9500' Siltstone Given these assumptions and inputs, the base case of 200,000 bbls of injected fluid predicts upward fracture growth of 1072' making the top of the fracture at 3875' TVDSS. This is well below the Inlet floor. The fracture half length of 562' does not endanger any wells or hydrocarbon bearing sands. Fi ure 1 presents a plot of the base case frac geometry. Plotted on this graph are total frac height and total frac half length as a function of injection time. Growth stabilizes into a radial shape after about 15,000 bbls of injection. -Total frac upward growth is calculated to be 1072', downward growth is 165', for a total frac height of 1237`. The total frac half-length is calculated to be 562'. The overall frac shape is approximately a circle that has been shifted up relative to the pertorated interval, because it is easier for a frac to grow up than down. Fi ure 2 presents the fracture in cross section, with the perforated interval indicated at 4947' - 4965' TVDSS. The fracture is expected to take a N25E and S25W orientation following the fold of the structure which would naturally be perpendicular to the direction of least principle stress. Fi ure 3 presents the fracture width profile in side view with a maximum fracture width of 5.0 inches. The majority of the frac volume is above the pertorated interval. Fi ure 4 presents the expected pressure above fracture gradient as a function of pumping time. The fracture gradient was estimated to be 0.95 psi/ft based on leak off test information. Maximum pump pressure is expected to be when pumping flush water and is calculated as follows: TVD x Frac Gradient + Net Frac pressure -column of the fluid being pumped 4947' x 0.95 psi/ft + 28 psi - 4940' x .45 psi/ft = 2501 psi Note: This is just an estimate and should not be used as a maximum allowable pumping pressure. • • 0 N ,-F~ V J T T I J Q O U O Z ~ W '.... Z Q `~ V rn L 005G OOZL 006 009 OOE T I I I I I I `~ s 1 1 1 ~`~ ~\`~~~- 005G OOZL 006 009 00£ (~~} uoi~e~~auad O 0 0 0 T 0 O O .-- O O 0 0 O ~~ .~ N ~_ f- Mar 31, 95 UNOCAL GRANITE POINT 44-11 3000 Stress (psi) 5000 TVD At Shut-In StimPlan 2.50 3800 4000 4200 4400 4600 4800 5000 5200 5400 400 800 1200 Fracture Penetration (ft) • • • • Mar 31, 95 Inn.-, ... UNOCAL StimPlan 2.50 GRANITE POINT 44-11 i . ~ ~ ,~ „ vvv ~~ress ~psi~ ~~v 0 -5.0 Width (in) 5.0 3800 4000 4200 4400 4600 4800 5000 5200 5400 V '' Max Width 5.0 in ~ • 0 N C _~ ,~J V / T T 1 J Q O U O Z ~ W _~ z a L o•o~ L 0'OE 0'OZ 0'0 L (isd) aanssaad ~aN O O O O T 0 O O r .C ~--' 0 0 0 0 0 • • Appendix F ~ ! ~ '~'~> Kam. ,.... - • - • -., ~. ~., SEP 5 i98~ ~`° ~ `"~ 1 ~ ~:- ,. Notice of Public Hearing !-?~, ' -=~ , '~-' - :n ~`-~1,, ~,~,~ STATE OF ALASKA ~.,,~ Alaska Oil and Gas Conservation Commission Re: The application of UNION OIL COMPANY OF CALIFORNIA (Unocal) for an Area Injection Order for the portion of the Granite Point Field developed by the Granite Point Platform. The Alaska Oil and Gas Conservation Commission has been requested, by letter dated September 9, 1986, to issue an order for area injection to provide authorization for utilizing exist- ing service wells permitted in accordance with 20 AAC 25.005 or 20 AAC 25.280 to inject fluids underground for purposes of enhancing oil recovery from the Granite Point Middle Kenai Oil Pool, as defined by Conservation Order No. 76. Parties who wish to protest the granting of the referenced request are allowed 15 days from the date of this publication in which to file a written request for a hearing. The place of filing is the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501. If such a rotest and request for hearing is timely filed, a hearing on t e matter wi oe held at the above address at 11:00 AM on October 13, lytt6, in con ormance wit AA a Baring is to e e , intereste parties may con~irm~this by calling the Commission's office, (907) 279-1433, after September 29, 1986. If no such rotest is timely filed, the Commission will consider t e issu- ance o t e order wit out a Baring. Lonnie C. Smith Commissioner Alaska Oil ~ Gas Conservation Commission Published September 12, 1986
