Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
2017 Oooguruk Unit
C CAELUS Energy Alaska March 22, 2018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dale Hoffman, CPL Manager, Land and External Affairs dale. hoffman@caelusenergy.com Direct: 907-343-2108 Cell: 907-830-2571 MAR 2 2 2018 Delivered by Hand 2018 Annual Reservoir Surveillance Reports Oooguruk-Kuparuk, Oooguruk-Nuigsut and Oooguruk-Torok Oil Pools Dear Commissioner French: The Alaska Oil and Gas Conservation Commission (AOGCC) approved pool rules for the Oooguruk- Kuparuk, Oooguruk-Nuiqsut and Oooguruk-Torok pools within the Oooguruk Unit as Conservation Orders 596, 597 and 645, respectively. Rule 9 of the orders requires filing annual surveillance reports, which are attached hereto. We will schedule a meeting with AOGCC staff to discuss the reports in detail. In the interim, please let us know if you have any questions or require additional information regarding the attached. Sincerely, Dale Hoffman Attachments DUPLIcATE 3700 Centerpoint Dr., Suite 500 • Anchorage, AK 99503 - Main Line: 907-277-2700 - Fax: 907-343-2190 - www.caetusenergy.com CC� CAELUS Ener g y Ataska RECEIVED MAR 2 2 2018 Annual Reservoir Surveillance Report Oooguruk-Kuparuk Oil Pool Oooguruk Field April 1, 2018 DUPLIcArE Table of Contents SUBJECT PAGE 1.0 Progress of the Enhanced Recovery Project.................................................................1 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool ........................1 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring....................................1 4.0 Review of Pool Production Allocation Factors and Issues Over the Year ..................2 5.0 Reservoir Management Summary..................................................................................2 ATTACHMENTS ATTACHMENT A: Kuparuk Voidage Balance by Month 2017 ................................................4 ATTACHMENT B: Map of Kuparuk Well Locations................................................................5 ATTACHMENT C: Form 10-412 Pressure Report for Kuparuk................................................6 ATTACHMENT D: Kuparuk Reservoir Pressure Map — 2017 ..................................................7 ATTACHMENT E: Kuparuk Annual Reservoir Properties Report Form 10-428 .......................8 Caelus Natural Resources Alaska, LLC 1.0 Progress of the Enhanced Recovery Project The Oooguruk-Kuparuk Oil Pool (OKOP) development includes eight wells: ODSK-13i, ODSK-14, ODSN-29 Kuparuk, ODSK-33, ODSK-35Ai, ODSK-38i, ODSN-40i Kuparuk, and ODSK-41. The locations of the OKOP wells are shown on Attachment B. Currently three producers (ODSK-14, ODSN-29 Kuparuk and ODSK-41) and two injectors (ODSK-35Ai and ODSK-38i) are active. The ODSK-33 well is inactive due to high water cut, the ODSK-13i well remains shut-in for long term pressure fall-off monitoring, and the ODSN-40i Kuparuk is currently shut-in due to limited injection capacity. A rig workover to complete the ODSN-29 Kuparuk interval and run a selective single completion concluded on September 6, 2017; tract operations were initiated on October 20, 2017. The interval is producing consistently at approximately 1,500 BOPD with cumulative production through December 31, 2017 of 114 MSTB. While the Kuparuk testing has temporarily shut-in Nuiqsut production from the ODSN-29 well, the long term plan, which requires AOGCC approval, is to commingle production from the two pools at this OU location or alternate production from each zone as the Kuparuk is much more prolific and is currently at a higher pressure than the underlying Nuiqsut in the area. Annual average daily OKOP production for 2017 was 748 BOPD. Total oil production during 2017 was 273,009 barrels for a total 8,782,689 barrels since field start-up. Average daily OKOP water injection for 2017 was 587 BWPD. Total water injection in 2017 was 214,170 barrels and 14,707,977 barrels since the start of the project. 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool Ten pressure surveys were reported from seven OKOP wells during 2017; the pressure survey results are presented in Attachments C and D. Overall, the pressures in the Kalubik fault block indicate pressure stabilization due to historical voidage replacement, excluding the ODSK-41 area which continues to show limited communication to offset injection wells. Pressures from the ODSK-13i injection and fall off test indicate the western Ivik block has relatively low transmissibility and is not in hydraulic communication with the main Kalubik block development area. Initial Kuparuk pressures measured in the ODSN-29 Kuparuk eastern Ivik well confirmed communication with the main Kalubik fault block, ODSK-38i, but not to ODSK-13i in the western Ivik fault block. 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring A chemical tracer program was initiated in May 2012 and completed in 2014. Tracers were injected into ODSK-35Ai and ODSK-38i. Within 20 months of initial injection tracer concentrations were observed in ODSK-33 and ODSK-14 from ODSK-35Ai. To date, Caelus Natural Resources Alaska, LLC Page 1 ODSK-38i tracer has only been seen in minor amounts in ODSK-33. Produced water samples for ODSN-29 Kuparuk did not show signs of either tracer. 4.0 Review of Pool Production Allocation Factors and Issues Over the Year Production from the OKOP, Oooguruk-Nuiqsut Oil Pool (ONOP), and Oooguruk-Torok Oil Pool (OTOP) is commingled at the surface into a common production line. Allocation between the pools is based on the ratio of total production for a pool to the total production for the Oooguruk Unit. The pool allocation factors for 2017 are: ONOP: 93.6% OKOP: 5.9% OTOP: 0.5% Theoretical production for individual wells for all pools is calculated on a daily basis. During 2017 wells were produced with chokes at 100% most of the time due to the capacity of the production line. Daily theoretical production for a well was calculated using the data from the most current well test and the amount of time a well was on production for a given day: Minutesproduced xDailyRate(BOPD) werrrev = TheoreticalDaily Production 1440Minutes day The daily allocation factor for the unit is calculated by dividing the actual total production for the day by the sum of the theoretical daily production for each individual well. Daily allocated production is assigned to each well by multiplying its theoretical daily production by the daily allocation factor. The average daily allocation factor for 2017 was 1.0306. 5.0 Reservoir Management Summary The Alaska Oil and Gas Conservation Commission (AOGCC) issued pool rules under Conservation Orders No. 645, 596 and 597 for the OTOP, OKOP and ONOP, respectively. While there is no subsurface commingling, unitized substances produced from the three oil pools are commingled on the surface. Area Injection Order No. 33 authorizing the injection of fluids for enhanced oil recovery in the OKOP was issued by the AOGCC in 2008 and injection commenced in 2009. The OKOP production continued as projected from horizontal producers ODSK-14 and ODSK-41. Eastern Ivik fault production was established from ODSN-29 Kuparuk via a selective single completion workover. Initial Kuparuk pressures measured in the ODSN- 29 Kuparuk well, 2,989 psi at 6,050 ft TVDss, are consistent with pressures measured Caelus Natural Resources Alaska, LLC Page 2 in ODSK-38i within the main Kalubik fault block, but not with the pressures in the ODSK-13 well in .the western Ivik fault block (refer to Attachments C and D). Additionally, since initiating Kuparuk production from ODSN-29 there has been no change in the fall-off trend in the ODSK-13 well. Consequently, a request has been submitted to expand the Oooguruk Kuparuk Participating Area to include the mapped relatively thick area around ODSN-29 on lease ADL 355036. Future development plans of the expanded area are contingent on the longer term performance from the well. ODSK-38i is the primary injector for the OKOP waterflood. Because the OKOP is a mature dual porosity system, with highly variable matrix permeability and open fracture networks, voidage replacement has been gradually reduced, currently 70%, to minimize waterflood by-pass while stabilizing the reservoir pressure and GOR, refer to Attachment A. The estimated average reservoir pressure is currently 2,800 psi at 6,050 ft TVDss and the average annual producing GOR is 702 SCF/STBO (refer to Attachment E, Kuparuk Annual Reservoir Properties Report Form 10-428). As a result, the producing OKOP water oil ratio increases have slowed and oil production has remained very stable. A simulation model has been maintained and updated to assist in reservoir and flood management decisions in the OKOP. Caelus Natural Resources Alaska, LLC Page 3 a a d w m Ln N O N N m N n N u Eco LT .-L m N � n m Ln w rn n w .-+ w 0 n La O C M C +� n n w w w w w w w m a1 O N C U N R to I.n L17 LC? t.n Ln 4n to Ln Ln, L? LQ LO p � � N m ei t i m? R m rn o w n d r_ N m Q. It IF r, a -i Pi e-1 c-1 ci N [ab G U 7 m r Ln V' N N IL u CC n 0 00 ri N O O Ch 07 m to co ,w •O K C 4 (D M w to m cr d' h m m .� '-i rl ♦-I .1 ri M U.Fp O CC r N m Ln it O w O h > c LD r -L N CN m m CV vel N H N N 'O C y h w O O M .-1 a1 Ln d enM m Z c�c Ut N [Y'1 �--� O r1 N In 'y 'y en .-+ 6u1 C .F Lo m N 00 C L e-1 N N M cr m N V a a d cr N m N N C14 Ln m m m N .� w u m LT .-L m d• cr cr LO LT m Ln n ai O C L C�jL Cf Ln Ln Ln Ln Loo Lo LLS w LD w h U N `^' N 0 N o N N N o-ci N N N � N v -I a -L vi ei _a+i rl rl s•� ri a-1 wl vi ri m? R m rn o w n d r_ N m Q. It IF r, a -i Pi e-1 c-1 ci N V U rm-4 .1-t .h•1 mm Ul w N CL to co ,w •O K C M w to m cr d' h m m n U.Fp o O O CC A A w .-+ N m Ln it O w O h > c LD r -L N CN m m CV vel N H N N 'O C � m e O d .-+ ` Lo m N 00 C L e-1 N N M cr m N V b °: a w 'H m Ln er O w O n eq M 7 r -t N � N m N e -I N a n co A A L I cu �-4 Ln N •-i 00 � cac u M cr to O cr m Lr t " In E .^1 tt LO m to O O N � m r-1 a .- 1 ri ri N N r w 00 M v a a N n LO u-) %r N n -4 LO Ln cn m a1 E u 3 w Ld 00 LO m N m m n" LU m n 0 ¢ N N m m cr ar cr kr Ln Ln w n 0 v H ci N 0 N o N N N o-ci N N N N CN m? R m N O m0 m h rt n N O� r- � ON M V rm-4 .1-t .h•1 mm Ul w CL to co ,w •O K M w to m cr d' h m m n o O O N h N > N 'O 7 m .-+ Lo m N 00 e-1 N N M cr m N V a n co A A L I m �-4 Ln N •-i 00 � O u N m Lr t " In LD .^1 tt LO m to O O N � m r-1 N .- 1 ri ri N N r w 00 M 10 (n N N G C ri H r-1 en -i ri ri N �U+ T Co E u -Q Q Lm O Z p r` U N a ATTACHMENT 13: Map of Kuparuk Well Locations ADI -389955, C) ADI -36960 ADL389959 :?� ADL31 9� \\ODSK-13 Nk� OOSk3541 \ 013,'-�-14 01,77 DSK -"x , ODI ADL355037 A' L355 6 'N*b K-33 ADL355039 N W+E S 0 .", I\ ADL389954 API -3$9 52 ADL38 51 \� Legend Kuparuk Pool Proposed OKPA Expansion Area Kuparuk PA Unit Boundary Lease Boundary Township Boundary Caelus Natural Resources Alaska, LLC Page 5 `iJ cu UD m CL m m J U N tl r tl� M O C N VD t0 YJ tl O O W N O1 W d [p W W o5 th of fJ N N O� N rn N rn N ni ❑ N v � wt n N O N C9 ~ N n 4 U C E chi � LU `= O C7 iq ❑ � It" uoi 0 �bcr uoi N ❑ � a D � t N 4. M D iv W LL d w❑ W W m Of W � tl g W O tl Q u Q n d 0 M M N N N N N ai m � E2 m r1 Cl C5 fG O ❑ o m o t0 N tL LL'1 10f1 �l z �— N v o i LO m �❑ CL " ~ E o W o U c a u m o m z Q W a U < oo 2 d z !' 2 u `° Vi ^ d da- a a d d a a p, V g� •A � 2� o � e rn � m � N �t, �n m D z W oma~ O W O z ❑ N m N e o s o (n (9 Y. w Li 0 o Q c �i m m M .n �2 so N e v M cv Ti 2 ❑O> W Im �' c F r M b o m ) o in 0 M o o rn M o D U) W a � F T c0 sp Kt Lfl b W W N w N c o Ny G � a m rn D Y U D O O O O P D O � O 2 d C tl (gyp CL N d o � a c t= mZ5 U o 2 2 O O O �' $ �_' O O u m o CD YS y O � O O O v W a wN Eo S O O O o O O b O O N S O O O S O O O O O N d D � Z N O O O OO b O QtN'l fN'1 cN+l CN9 m M rNi tN+1 M 3 0 t!t �Ll u9 iit u7 �Y) u7 uP� u'1 ul J N � °1 i0 W J w n j XY Y N Y N Y Y Y Y Y Z fn fn U C O` j a a o a 0 ❑ 0 ❑ 0 0 o 0 a a o 0 0 0 0 ❑ 0 a` 0'6 v 0 O o O a m M L r U cu UD m CL ATTACHMENT D: Kuparuk Reservoir Pressure Map — 2017 30 29 28 26 ,. ♦ 25 30 29 3e3-- 3a ODSK-13 3838 3B '. '�,, 'st 32 Kuparuk Pressure PSI Caelus Natural Resources Alaska, LLC Page 7 - ODSKaw � 2910 _ s'� ' ' ' 1 0 [� 1,249. 1,360 - 1,300 - 1 400 1 6 5 � a ODSK-14 294b] - 3 7 $N-29 1 400.1 566 e 1,500- t Eco ODS 989 q@ [ 7.600. 1,700 1,700.1.800 U 1,800 - 7,900 1.960 - 2.000 7 8 '. 9 - _ -T-- 11 '� 7 L_J 2,060'- 2.100 2.100 - 2,200 2,200 2300 2.300 - 2.400 2,400.2 500 - 2,500.2.600 i © 2,600. 2.700 18 17 16 15 14 .:erg ,J 182,700-2.800 s Q 2,800.2 900 tt Q 2,900. 3.000 51 3,000 - 3.100 3,100 - 3.200 = 3,200 - 3.300 t9 20 21 22 23 I �4 19 = 3,300.3400 ., 0 3,400, 3,500 •...�j 3,500.3,600 SSS _ Q 3,600 - 3 700 1. 3 700 - 3.800 t 3,800 3.900 X 29 28 27 26 25 Legend Kuparuk Pool Kuparuk PA % 35 30 _ _ 0 0.5 1 2 Miles `, Proposed PA Expansion ,350000 46000C 470000 480000 Caelus Natural Resources Alaska, LLC Page 7 Go N � 0 _ E 0 U. r- 0 � @ � � ■ @ W CL 20 Z � U � Q ' ■ @ w \ � re J § � 9 J j 2 g \ u j§ E ,}ƒa z k _ 2ƒ« LU \ ■ §!§_, ±[ a / § a §2 ■ « * ! §\ k }\)4 § C) ■ w ! a;# f ■ = �a :,�§5= ,. 2 k J ® \f f !� « ) \ � re J § � 9 J j 2 g \ u CA -PLUS Ataska MAR z 2 2018 G Annual Reservoir Surveillance Report Oooguruk-Nuiqsut Oil Pool Oooguruk Field April 1, 2018 DUPLICATE Table of Contents SUBJECT PAGE 1.0 Progress of the Enhanced Recovery Project.................................................................1 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool ........................2 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring....................................2 4.0 Review of Pool Production Allocation Factors and Issues Over the Year ..................3 5.0 Reservoir Management Summary..................................................................................3 ATTACHMENTS ATTACHMENT A: Nuiqsut Voidage Balance by Month 2017 .................................................5 ATTACHMENT B: Map of Nuiqsut Well Locations.................................................................6 ATTACHMENT C: Form 10-412 Pressure Report for Nuiqsut .................................................7 ATTACHMENT D: Nuiqsut Reservoir Pressure Map — 2017 ...................................................9 ATTACHMENT E: Nuiqsut Annual Reservoir Properties Report Form 10-428 ......................10 Caelus Natural Resources Alaska, LLC 1.0 Progress of the Enhanced Recovery Project At the end of 2017 there were 28 active Oooguruk-Nuiqsut Oil Pool (ONOP) development wells, including 18 producers and ten injection wells. During 2017 seven ONOP workover operations were completed: ODSN-02, ODSN-04, ODSN-16, ODSN- 17, ODSN-28, ODSN-29 and ODSN-31. The workovers included recompletions to improve flow efficiency by installing electrical submersible pumps (ESPs) or a 2 7/8" gas lift completion, three well integrity repairs, and a test of the Kuparuk in the Ivik fault block via a dual Nuiqsut and Kuparuk completion in the ODSN-29 wellbore (the Nuiqsut was completed in 2013). The workover program started in August 2017 and was completed in November 2017. The locations of the existing ONOP wells are shown on Attachment B. Within the central Kalubik fault block, ODSN-01A, ODSN-24, ODSN-25, ODSN-31, ODSN-36, ODSN-37 and ODSN-42B continued to produce in 2017. The wells are supported by water and gas injection in ODSN-19i, ODSN-26i, ODSN-32i, and ODSN- 34i. Production from ODSN-01A was cycled on and off during the year to manage voidage replacement and the producing gas oil ratio (GOR). ODSN-10, ODSN-16, ODSN-17 and ODSN-18 continued to produce throughout 2017 in the Colville Delta fault block, supported by water and gas injection in ODSN-23i and ODSN-15i. The ODSN-10 well was drilled in the northwest area of the block, near the truncation, and was completed during the 2016 winter fracturing season. The well successfully defined the potential of the area and also demonstrated very high production potential. Offtake from the well has been restricted to manage voidage replacement and the producing GOR. Within the northern Ivik fault block, ODSN-02, ODSN-04, ODSN-06, ODSN-28 and ODSN-29 continued to produce in 2017. ODSN-29 Nuiqsut production was shut-in in August, 2017 for the workover and selective single recompletion; Nuiqsut production from the well has remained shut-in pending evaluation and testing of the Kuparuk in the area from the well. The long term plan, which requires AOGCC approval, is to commingle production from the two pools at this location or alternate production from each zone as the Kuparuk is much more prolific and is currently at a higher pressure than the underlying Nuiqsut in the area. As planned the ODSN-07i well was converted to injection in January, 2017 thus increasing voidage replacement along with continued injection from ODSN-03i. Proactively, production from the Ivik fault block has been restricted when feasible to minimize producing GOR increases until the injection response is fully established. ODSN-22 and ODSN-43 in the southwestern ONOP continued to produce throughout 2017 supported by water and gas injection in ODSN-48i. In order to manage voidage and producing GORs production from the pattern has been restricted during the year by alternating production cycles from the two wells. Annual average daily ONOP production during 2017 was 11,834 BOPD. Total oil production from the ONOP during 2017 was 4,319,382 barrels and is 23,322,547 barrels since field start-up thru 2017. The annual average producing GOR was 1,264 SCF/STBO. Caelus Natural Resources Alaska, LLC Page 1 Annual average daily ONOP injection during 2017 was 11,339 BWPD and 2,950 Mscfd. Cumulative water injection in the ONOP during 2017 was 4,138,854 barrels and 18,649,934 barrels since the start of the project. Total gas injection in the ONOP during 2017 was 1,077 MMscf and 9,561 MMscf since the start of the project. Throughout 2017, water and gas injection continued in the ONOP; however, KRU water supply was restricted or shut-in for approximately 97 days from March through July for maintenance operations which reduced overall ONOP voidage replacement. Attachment A details the 2017 voidage balance for the ONOP. 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool Thirty-six pressure surveys were reported from 21 wells. The details of the pressure tests and interpretation can be found in Attachments C and D. The estimated average reservoir pressure is currently 2,680 psi at 6,350 ft TVDss (refer to Attachment E, Kuparuk Annual Reservoir Properties Report Form 10-428). 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring Well surveillance equipment was placed in the liners of seventeen Nuiqsut wells during the initial completions. The systems are in-place to assess production profiles and continuity along the lateral via target fluid tracers, which are monitored and analyzed by collecting surface fluid samples during restarts and over time. The tracers have recently been used to assess hydraulic connectivity along the laterals to evaluate the need for coil tubing interventions to clear any sand or debris blocking the flow path. The tracers will also be used, where available, to help diagnose water breakthrough in the future. An extended reservoir surveillance and remedial program is ongoing in the ODSN-03i pattern which had early water injection breakthrough in both offset producing wells, ODSN-02 and ODSN-04. In July 2016 plugs were placed in the lateral of ODSN-03i to isolate suspected thief zones and the response was monitored in the ODSN-02 and ODSN-04 wells. A thief zone was identified in ODSN-03i in 2017 and injection restored to the lateral. Remediation of the ODSN-03i thief interval is approved and planned for August, 2018. Caelus Natural Resources Alaska, LLC Page 2 4.0 Review of Pool Production Allocation Factors and Issues Over the Year Production from the ONOP, Oooguruk-Kuparuk Oil Pool (OKOP) and Oooguruk-Torok Oil Pool (OTOP) is commingled at the surface into a common production line. Allocation between the pools is based on the ratio of total production for a pool to the total production for the Oooguruk Unit. The pool allocation factors for 2017 are: ONOP: 93.6% OKOP: 5.9% OTOP: 0.5% Theoretical production for individual wells for all pools is calculated on a daily basis. During 2017 wells were produced with chokes at 100% most of the time due to the capacity of the production line. Daily theoretical production for a well was calculated using the data from the most current well test and the amount of time a well was on production for a given day: Minutes produced 1440 Minutes day xDailyRate(BOPD)well,,,= TheoreticalDaily Production The daily allocation factor for the unit is calculated by dividing the actual total production for the day by the sum of the theoretical daily production for each individual well. Daily allocated production is assigned to each well by multiplying its theoretical daily production by the daily allocation factor. The average daily allocation factor for 2017 was 1.0306. 5.0 Reservoir Management Summary The Alaska Oil and Gas Conservation Commission (AOGCC) issued pool rules under Conservation Orders No. 645, 596 and 597 for the OTOP, OKOP and ONOP, respectively. While there is no subsurface commingling, unitized substances produced from the three oil pools are commingled on the surface. Area injection orders authorizing the injection of fluids for enhanced oil recovery in the Oooguruk-Torok, Oooguruk-Kuparuk, and Oooguruk-Nuiqsut reservoirs were issued by the AOGCC as Area Injection Orders No. 37, 33 and 34, respectively. Injection commenced into the ONOP in 2009. During 2017 the ONOP Under -Saturated Water -Alternating -Gas (US -WAG) was expanded with the conversion of ODSN-07i in January, 2017. Reservoir management included maximizing voidage replacement and managing producing gas oil ratios by cycling producing wells on and off production where possible operationally. The current cumulative voidage replacement ratio is at 53% which is consistent with ratio of injection wells to producing wells and the overall ONOP pattern layout. In general producing Caelus Natural Resources Alaska, LLC Page 3 wells in the more mature flood areas have seen GOR stabilization and stabilized or increased oil production rates. However, the injectivity of the non -mechanically diverted fracture stimulated ONOP injection wells has been declining over the past several years. The lower injectivity will result in less water throughput and reduced ultimate recovery. Current injectivity of these wells is at approximately one third of the modeled theoretical potential. Whereas, the ONOP mechanically -diverted fracture stimulated injection wells, due to the large increase in surface area open to flow, show very high sustained injection rates and associated throughput. Potential injection damage mechanisms include reservoir fines migration, clay swelling and possible blockage of pore throats from solids in the seawater injection system. Improving and sustaining ONOP injection and throughput will increase ultimate recovery. Consequently, Caelus is evaluating multiple projects and well treatments to increase water injection rates including periodic stimulation treatments, surfactant treatments and increasing the injection pressure by installing a water injection booster pump. Technical estimates indicate that increasing the injection pressure for the non -mechanically diverted fracture stimulated ONOP injection wells could increase oil recovery significantly. Higher pressure injection tests are planned for 2018 along with other remedial actions. Additionally, the ONOP fracture containment model for EOR operations will be updated to incorporate fracturing results to -date and the results of the high pressure injection tests in order to revisit the Area Injection Order 34 Finding 13 which currently limits the surface injection pressure to less than 2,900 psi. Individual well and pattern surveillance data will continue to be collected to monitor performance and improve recovery. A simulation model has been maintained and updated to assist in reservoir and flood management decisions in the ONOP. Caelus Natural Resources Alaska, LLC Page 4 r N N LL V a) To, a V L77 MN OO = rl h rl bO N t Nry N M Ghi 0Vg7 T eepp O h uu'�7 4 et u�7 u� ,c w OC O R7 lT P. Q tJ5 u'a 1� BNi rl :7 b? C' N 09 N Oi t01� h ti d M M M ti N N 4Ci of !t a 07 e-1 +W H N H N aa N 'i N N N SI' [F C V n'1 O C hpp�1 0 LQ 0000 m 50 d rl ON'1 Ol N N O rl ri ri N b Ghii m OO M1 n eT m N } •C rl rl N RI al Lr e n M 61 rr�j V C M U1 a N 01 -n h M m A rq h a t0 .4 Ch m i0 N N V ri N 00 m ' Q 00 m 'O � U'�1 of e-1 N N' M cr d' d' ui lfl SLS GJ a Co - N o o lD A o Z 0, } 6'a 2 O �me� Ci O w m w O W php 00 09 C C � a O Ln �o m 05 eY p� '2 v1 m ul 00 in 0 m m app m uy N -r g a ? v �p To, v V L77 MN OO C Q. 5 m rl h rl bO oo lb N G N" Oil ep Ct h R d NN N NN M m M et et u�7 u� l0 w OC n +G +LY Y7 N N N N N M N N N Oi M M M 4' 4Ci of !t Q 0 N b � T SI' [F C eT n'1 O C hpp�1 0 LQ 0000 m 50 d ONO lA C1 Vl ON'1 Ol V rl ri ri N b Ghii m OO M1 n eT m N } >" V rl rl N RI al Lr e n M 61 •� W C t9 O O] M -n h M m A rq h a t0 .4 Ch m i0 N N V ri N 00 m ' Q 00 m 'O yyCr Gl cL vl Ln 'j' .-1 N M 'd' u1 i+' a FO Co - N o o lD A o d 0, N 6'a 2 O �me� Ci O w m w O W php 00 09 C � N co vCN v h+ ° m -r g v l v a v c O O O O d O pOO W 0 ci U, V cc CJ Co rl N O m Vt 0 1-, N To, v C Q. 5 m rl h rl bO oo lb N G N" Oil ep Ct h R d M Q d R M OO �B u1 w OC n +G +LY Y7 •t M a N .-1 ai Oi M M M 4' 4Ci of z v SI' [F C eT N 7 b Ghii m OO M1 n eT m N >" V rl rl N RI al Lr e n OO 61 ri a Co - N o o lD A o r, 0, 6'a 2 O �me� Ci O w m w O W php 00 09 14 N 7 LL 'O 0 ci V CL cc CJ Co rl N O m Vt 0 1-, N Q1 w 00 M y n aY vii a � a a s N 2 m ate.+ aoN�}1 N ri rl pi ^V Opp 00 W t!) 00 N r, a f� V C V '7 m m smi m m ch a C M N C: in m a m °° a O o � O V iy To, ATTACHMENT B: Map of Nuiqsut Well Locations ADU3 T P AW8996O Lai W OC�SN- 01 �k r f-1Of.DSN48 L N ADL355O39 W+E S ® Miles 0 0.5 1 2 3 4 ADL�79891 ' \ i L38995 ADL389949 `\ OOSN-0 i t\ \ 9 ADL389951 2B i Legend Nuiqsut Pool � —� Proposed Nuiqsut PA Expa Current Nuiqsut PA QUnit Boundary Lease Boundary Township Boundary Caelus Natural Resources Alaska, LLC Page 6 a) CD a_M 31k 4 rY Ell 70 6 otol Q 6 . .R . . . . . . ® . . . . . . . C, jj-i g A F �91 o LU g o 9 2 0i? 3 g g 2 g 2 v° 2 z Q zo 9L � !q'l, A try Ix 00 � > J 0 W I 1 2 9 9 ri 0 Lu 15w z 2 z z z z z z 2 z z Si S 2 pa 0 0 0 0 a 0 a 0 0 a a 0 O 0 o o r 3! 2 z z 2 2 a) CD a_M ai, co V) (1) 0 U) (1) Tf Z cn a) ca 0 o LU 19 Z 0 w ce uj LL z w 00 CL 0 w 14 � w �j 91 1 i 1 i I I I w . — z z 2 za z r, O 0 0 O 0 0 0 2 2 z 2 ai, co V) (1) 0 U) (1) Tf Z cn a) ca ATTACHMENT D: Nuiqsut Reservoir Pressure Map — 2017 12 7 9 �70 .1 12 7 8 9 10 12 16 .•�` 16 •'.` 15 ! 14 13 18 17 16 15 xN ±14 19 20 y1,a J� �C, f 22 23 24 9 % 20 3 21 22 T14NR y:. T14, 7E �— — T14NR69 16� If 1 eau tl 25 30'.. 29 28 29 'Si OOCm ! Jas7 o�0sr1-r71 Q : , ma 5N-t9i 1 38 31 � 3�' JJea' 33 � � ; Jt92 �. 32� �x 9N 291 a1c 009H -2J i ..0J9G.J laaJ 1.,, •\ I Q e;o 6 I f = n-zaw r OCc , 2fi61 t u SW-1fi ry 9f 12 7 7 Q,2ix, .t Q;,00 3m Q :u nm E Ca h; 13 18— 1 17 15 4 13 1 17 T13 7E N29 T13NR6E - Q.-m.,mc 0� - r \ 411 y` '� T13N'6E Q•.: = CJl 24 { 19 w 20. d a. 21 23 7. `�24 19 20 -111 ��•� / 1��. ©M4 nr. 25 30 29 28 27 25� 30 29 Le9anC 0 0.5 1 2 Miles 33 34 35 38- 31 '� 4, 32 Caelus Natural Resources Alaska, LLC Page 9 w C14 qt O V- E E 0 U- Ita 0 CL ■ � � m _■ Z � W a 2 O 2 CL U �0 > Q § @ � ■ A k\ \( /* \ 4§ £ )|k■ E rile z ■ w ;�7§# § 2 IL ;- \ w \§2�§: ■ 2 a ;£� 00 § e K \\§k § U 2 ! &d£� �7=7l ■ ■q2§; - U w \ � w»�,_■ � - 2 � J / \ EE f k § ! k ]� 7 - w ■ A CAELU S fli.lf Alaska RECEIVED CC� MAR 2l 2018 Annual Reservoir Surveillance Report Oooguruk-Torok Oil Pool Oooguruk Field April 1, 2018 Q�p�\CASE Table of Contents SUBJECT PAGE 1.0 Progress of the Enhanced Recovery Project.....................................................1 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool.............1 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring ......... 2 4.0 Review of Pool Production Allocation Factors and Issues Over the Year ....... 2 5.0 Reservoir Management Summary.......................................................................2 ATTACHMENTS ATTACHMENT A: Torok Voidage Balance by Month 2017 ............................................4 ATTACHMENT B: Map of Torok Well Locations............................................................5 ATTACHMENT C: Nuna Torok Phase 1 Map View.........................................................6 ATTACHMENT D: Form 10-412 Pressure Report for Torok............................................7 ATTACHMENT E: Torok Reservoir Pressure Map — 2017 ..............................................8 ATTACHMENT F: Nuiqsut Annual Reservoir Properties Report Form 10-428 ................9 ATTACHMENT G: ODST-46 Pressure Monitoring and Daily Injection Volumes ...........10 Caelus Natural Resources Alaska, LLC 1.0 Progress of the Enhanced Recovery Project At the end of 2017 there were two active Oooguruk-Torok Oil Pool (OTOP) development wells, ODST-45A and ODST-46i. Production from ODST-45A was successfully restored in April 2017 following a coiled tubing stimulation to remove scale build-up in the lateral. Injection in horizontal well ODST-46i was also re-established after suspension of drilling operations and repairing several slow tubing leaks to the inner annulus through leaking gas lift mandrels. A workover was conducted on ODST-39 in August 2017 to pull the ESP and run a gas lift completion string. Uunfortunately, during the decompletion the well's casing integrity was compromised and the well has been suspended. ODST-47 is non-productive due to a mechanical failure in 2013. The two Nuna Drillsite 1 (NDS1) wells, Nuna-1 and NDST-2, are suspended pending NDS1 development. The locations of the existing OTOP wells are shown on Attachment B. Caelus continues to pursue funding for Phase 1 of the Nuna Torok project (Attachment C) which would access resources inaccessible from the Oooguruk Drill Site (ODS) in and near the Colville River Delta using extended reach drilling from NDS1. The project lies two miles north-west of existing facilities at KRU Drill Site 3S (DS -3S). During 2017 Caelus re-evaluated and continued to optimize the drilling and facility construction schedule and cost in light of lower oil prices and uncertainty in the tax structure environment. Equipment, material procurement and module fabrication are currently suspended. Flowline installation is planned for the first quarter of 2019 or later and facility installation will occur prior to start up in 2019 or later. Annual average daily Torok production for 2017 was 62 BOPD. Total oil production from the OTOP during 2017 was 22,568 barrels and is 862,112 barrels total through 2017. The 2017 annual average producing gas oil ratio was 776 SCF/STBO. Seawater injection continued in ODST-46i and the well was monitored pursuant to the rules of Area Injection Order 37 (A10 37). Attachment F, in compliance with A10 37, Rule 9, details the well injection pressures and injection for the report period. Torok water injection was limited to 161 days in 2017, yielding a daily average water injection rate of 772 BWPD. Cumulative water injection in the OTOP during 2017 was 124,352 barrels and 743,352 barrels since the start of the project. In 2017 no gas was injected in the OTOP. Total gas injection in the OTOP is 171 Mscf since the start of the project. Attachment A details the 2017 monthly voidage for the OTOP. 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool Seven pressure surveys were reported from four OTOP wells during 2017. The extended pressure build ups in ODST-45A, ODST-39, and ODST-47 coupled with the ODST-46i falloff data, suggest similar levels of depletion and continuity in the ODS development area. The average OTOP pressure at 5,000 ft TVDss is estimated at 2,200 psi. Attachment D, E and F detail the surveys and relevant data. Caelus Natural Resources Alaska, LLC Page 1 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring Extended shut-in bottomhole pressure data from ODST-39, ODST-45A, ODST-46i and ODST-47 indicate good communication in the reservoir as evidenced by the equalization of the pressures over time (see Attachments D and E). 4.0 Review of Pool Production Allocation Factors and Issues Over the Year Production from the OTOP, Oooguruk-Kuparuk Oil Pool (OKOP) and Oooguruk-Nuiqsut Oil Pool (ONOP) is commingled at the surface into a common production line. Allocation between the pools is based on the ratio of total production for a pool to the total production for the Oooguruk Unit. The pool allocation factors for 2017 are: ONOP: 93.6% OKOP: 5.9% OTOP: 0.5% Theoretical production for individual wells for all pools is calculated on a daily basis. During 2017 wells were produced with chokes at 100% most of the time due to the capacity of the production line. Daily theoretical production for a well was calculated using the data from the most current well test and the amount of time a well was on production for a given day: Minutesp.adueea xDailyRate(BOPD)wei«es,= TheoreticalDaily Production 1440 Minutes day The daily allocation factor for the unit is calculated by dividing the actual total production for the day by the sum of the theoretical daily production for each individual well. Daily allocated production is assigned to each well by multiplying its theoretical daily production by the daily allocation factor. The average daily allocation factor for 2017 was 1.0306. 5.0 Reservoir Management Summary The AOGCC issued pool rules under Conservation Orders No. 645, 596 and 597 for the OTOP, Oooguruk Kuparuk Oil Pool and the Oooguruk Nuiqsut Oil Pool, respectively. While there is no subsurface commingling, unitized substances produced from the three oil pools are commingled on the surface. Area injection orders (AIOs) authorizing the injection of fluids for enhanced oil recovery in the Oooguruk-Torok, Oooguruk-Kuparuk, and Oooguruk-Nuiqsut reservoirs were Caelus Natural Resources Alaska, LLC Page 2 issued by the AOGCC as AIO No. 37, 33 and 34, respectively. Injection commenced into the OTOP in 2012. Reservoir management included maximizing voidage replacement by restoring and maintaining injection in the ODST-46i well. The current cumulative voidage replacement ratio is at 33%. A simulation model has been maintained and updated to assist in reservoir and flood management decisions in the OTOP. Currently, there are no plans to repair ODST-47. Consequently, Caelus has filed to contract the existing Oooguruk Torok Participating Area. Consistent with plans to expand the OTOP development to NDS1, a request to establish the Nuna Torok participating area has been prepared and is planned for submittal in 2018. The locations of the existing OTOP wells and planned Participating Areas are shown on Attachment C. Caelus Natural Resources Alaska, LLC Page 3 r CD N N U. M a) C c m O Ln N t`� 00 9 m U7 N [V O a m W h Ln LC 3 h h 00 h Ln Ct N t. C= 00 00 00 00 00 00 00 00 00 00 00 00 U Zn r1 4 . a -i rl ri .,1 r7 rl e -Ii s+l a-1 +ri W C O L N .m-1 h M N e!' d Lin C N O7 i' Z O m CC m C �y N m O N Ln in V N `'I '""� e-1 N .-i O a -i U, c� d7 m N n Ip ao m m� m m m m m Lp lD LD lQ W h h h h h h n h N N N N N N N N N N M C.I N CJ 3 m 00 m h O m m m o o p ro m C � � � 00 04 m N N M N d' aY {A 00 m m a O h n 00 00 00 OQ 00 00 00 00 O 00 m l0 LD tLO Ln h h N 7 m q O M Ct cF V1 LA h m Cf 7 a-+ N C A A Q m OC ko N O O a O Ln O O V O N N r.{ N N 'I cn L M� A m q Ln g N N N n L V .�1 O d .0 C CO 'V CL N O O O N Q O N e -I 14 N Ol m V C Y IPI aj a+V O C Vn 000L V c� d7 m N n Ip ao m m� m m m m m Lp lD LD lQ W h h h h h h n h N N N N N N N N N N M C.I N CJ It N f6 a. U J J (0 Y U) co Q 6n U 7 O N N w Z 6n 7 N l0 U 10 } u � m m N O O N m m m m m m m ct m Lo Ln Lo Lo Lo Lo ai oo m 00 0 0 0 0 7 7 W mcr m O a .-� N rt Ln ct O O O O N O A cn L M� A m q Ln g N N N n L V .�1 O 2 L m 0 00 Cl N C N m0 0 0 0 N b C Y IPI aj a+V O C Vn 000L m G N^ V O 01 n E LL Q ¢ In o a a � o V N It N f6 a. U J J (0 Y U) co Q 6n U 7 O N N w Z 6n 7 N l0 U ATTACHMENT B: Map of Torok Well Locations ADL389956 ADL389955 ADL379301 ADL389960 ADL389959 ADL389958 ----- --- ADL389954 ADL38995< ADL389950 ADL38994E OD 'r OD ADL35503 T-339 _ ADL355036 S 5A ADL389952 ADL389951 O T-47 NDST-2 ADL355039 ADL355038 NU A-1 Legend N Torok Pool w � '- Proposed OTPA Contraction S L- QCurrent Torok PA Q Miles Unit Boundary 0 0.5 1 2 3' 4 Lease Boundary QTownship Boundary Caelus Natural Resources Alaska, LLC Page 5 .e O L O L Q z W d L 2� Q N a� L Fa aN T- 1 r E O U. N 0) m CL IWI a N ❑ n � N N a h N 1 G n W s N C b O O O O O pO pO o m N 1(j-, TOJj n m m N w � m `m a` F - N a m c � c ❑ F- m m m `^ am `^ o m o ❑ �n 90 0 v a a a v m M J N N m m ~ ❑ C o El v E c u a o vi U a a co N G- `m a o cv M a c o` D H sz N en o U c " m 5 0 o m ui o a ho m O � a �. iz- _ Q C tem' O O O g O O O fel N � CLvi c n G rn rn m a rn rn m c ry N o (V G Fes- O Fc- o h 0 Fes- o Fes- O Fo- o 1�- J Y n ro n. uri i ,hn puri urs '� ca 10 0 a v O N a O O O $ ? ? i p 3 Y d U Q N N v mE Lu 0 o 0 0 0 0 0 0 0 0 0 0 o b m a y z x u M r!1 E ❑ rn M M o r M n M n M M � Q' c Cj J G D 26 E t 3 m m o m 9 E of tl m z E n co M NV v N 0 N C w o.� o j m z O O p N o O o o m n d p d Z)o a N 0) m CL IWI ATTACHMENT E: Torok Reservoir Pressure Map - 2017 450,000 460000 470,000 4801000 ._-----"" 31 32 — 3,1 34 T14NR7E 35 38 31 T14NR8E a2 33 i 6 5 \. 4 2 i e s 4 '� r _ f+ r OST�-0fiT-39 I 7 8 1715 9.�..... 77 12 7 8 9 r 1 & r OD 5A 6030000, 2017 18 17 ' g f 15 '.} m 13 18 17 16 j13NR7E \ �, T13NP8E ,y 20 21 $T-07 \. 24 19 20 21 B02G000 47 j NDST-2 Torok Pressure 30 i PSI 29 i 28 27 26 25 30 11 1,679 - 1.700 1,700 - 1 B00 NUNA 1 .. 1.800 - 1.900 f C— 1,900 -2000 @ 2,000 - 2.100 ai 12 33 - m 36 \31 2.100 - 2200 e0100DOi Q 2,200 - 2.300 2,300 - 2.400 r - Q 2,400 - 2,500 2500 - 2.600,1 4 3 2 1 6 Legend T12NR7E Torok Pool I _ _ r Proposed OTPA Contraction 0 0.5 1 2 Miles 11 12 7 Torok PA Caelus Natural Resources Alaska, LLC Page 8 \ ! x \ / 7t!!) � � ! e E , LL /t{! 0 E : y C 2■ ■ § (0 w 2 u " S § 3 LU Z)¢ a ;§:!• ; \ uj � § 2 )\§ƒ)! (n CL \ U S d \ k > $` ) ,!!;;» e wf\®)7\ : $lw,R c � 0 Z5 c � ..a x \ / ATTACHMENT G: ODST-46 Pressure Monitoring and Daily Injection Volumes (AIO 37, Rule 9) Caelus Natural Resources Alaska, LLC Page 10 Inj Pressure IA Pressure OA Pressure GAS INJ (mscid) WATER INJ (bbl/d) 2017 PI 27210C PI 27210G PI 27210H AVM AVM MONTH DAY MIN MAX AVERAGE MIN MAX AVERAGE MIN MAX AVERAGE Daily Total Daily Total January 1 1 251 251 427 427 427 3 3 3 0 0 January 2 250 251 250 426 427 427 3 3 3 0 0 January 3 250 250 250 426 426 426 3 3 3 0 0 January 4 249 250 250 425 426 425 3 3 3 0 0 January 5 249 249 249 424 425 425 2 3 3 0 0 January 6 248 249 249 424 425 424 2 3 3 0 0 January 7 248 248 248 424 425 424 3 4 4 0 0 January 8 247 248 248 424 424 424 4 5 5 0 0 January 9 246 248 247 423 424 423 5 6 5 0 0 January 10 246 247 247 422 423 422 5 6 6 0 0 January 11 246 247 246 422 422 422 6 7 6 0 0 January 12 160 1,490 401 326 434 403 6 35 10 0 0 January 13 461 810 1 3,021 659 2 186 11 0 0 January 14 612 1,454 1 3,020 1,085 -2 158 5 0 0 January 15 195 1,219 -5 3,022 807 -6 152 4 0 0 January 16 502 1,439 947 560 701 609 1 312 95 0 464 January 17 1,439 1,636 1,547 607 644 627 313 366 346 0 1,148 January 18 1 1,604 604 733 661 319 371 362 0 1,012 January 19 1,729 1,799 1,772 732 743 736 364 378 369 0 1,005 January 20 1,772 1,818 1,795 728 743 735 364 378 370 0 1,042 January 21 1,818 1,855 1,835 727 760 742 363 387 374 0 1,017 January 22 1,835 1,870 1,856 760 772 764 387 392 388 0 966 January 23 1,018 1,887 1,742 694 882 785 2S3 395 353 0 778 January 24 1,850 1,880 1,861 849 881 862 337 362 347 0 789 January 25 1,868 1,877 1,873 850 861 856 339 349 345 0 755 January 26 1,874 1,952 1,910 861 891 876 349 371 360 0 793 January 27 1,931 1,947 1,939 891 906 899 371 378 375 0 812 January 28 1,938 1,947 1,943 892 915 900 364 387 372 0 783 January 29 1,934 1,943 1,940 900 904 902 367 372 369 0 753 January 30 1,938 2,035 1,976 903 1,270 1,039 369 425 389 0 804 January 31 1,971 1,998 1,988 1,269 1,281 1,275 422 429 426 0 793 February 1 1,967 1,984 1,979 1,266 1,283 1,274 413 430 421 0 757 February 2 1,958 1,987 1,972 1,255 1,271 1,263 404 417 410 0 729 February 3 1,947 1,968 1,962 1,265 1,271 1,268 409 416 412 0 707 February 4 1,737 1,971 1,967 1,258 1,275 1,271 408 416 412 0 702 Caelus Natural Resources Alaska, LLC Page 10 February 5 1,372 2,119 2,038 1,235 1,414 1,364 364 439 421 0 820 February 6 2,114 2,134 2,124 1,414 1,436 1,426 439 449 443 0 880 February 7 2,125 2,144 2,135 1,429 1,436 1,432 439 448 443 0 858 February 8 2,138 2,159 2,148 -5 2,038 1,431 430 515 437 0 832 February 9 2,155 2,173 2,163 -3 2,811 1,498 427 602 437 0 828 February 10 2,168 2,175 2,171 1,499 1,508 1,503 421 428 424 0 816 February 11 2,170 2,183 2,176 1,507 1,515 1,511 426 431 429 0 806 February 12 2,176 2,183 2,180 1,502 1,514 1,507 418 429 423 0 797 February 13 21169 2,186 2,179 1,493 1,528 1,506 409 438 420 0 775 February 14 2,172 2,188 2,183 1,483 1,514 1,489 399 426 403 0 763 February 15 2,176 2,189 2,184 1,485 1,491 1,489 400 404 402 0 755 February 16 2,178 2,198 2,191 1,488 1,496 1,491 400 405 402 0 749 February 17 2,192 2,262 2,245 1,491 1,498 1,496 399 406 403 0 859 February 18 2,255 2,276 2,267 1,491 1,498 1,494 392 401 396 0 849 February 19 2,269 2,283 2,278 1,488 1,512 1,490 387 403 389 0 839 February 20 2,277 2,287 2,283 1,512 1,620 1,593 403 489 468 0 827 February 21 1,543 2,289 2,195 1,479 1,579 1,523 310 454 389 0 707 February 22 2,238 2,382 2,317 1,570 1,686 1,639 364 418 390 0 799 February 23 2,374 2,401 2,390 1,686 1,696 1,692 414 420 417 0 914 February 24 2,390 2,406 2,399 1,696 1,710 1,705 416 424 421 0 878 February 25 2,392 2,419 2,410 1,688 1,703 1,694 400 417 407 0 880 February 26 2,406 2,421 2,417 1,688 1,699 1,695 396 402 399 0 873 February 27 2,409 2,440 2,427 1,699 1,708 1,704 397 400 399 0 875 February 28 2,417 2,458 2,437 1,704 1,710 1,707 388 399 393 0 876 March 1 2,452 2,460 2,455 1,706 1,719 1,710 384 390 386 0 898 March 2 2,450 2,464 2,458 1,719 1,737 1,726 389 402 394 0 882 March 3 2,453 2,471 2,463 1,737 1,753 1,745 399 412 406 0 873 March 4 2,440 2,528 2,501 600 1,802 1,499 266 410 374 0 990 March 5 1,785 2,476 2,364 688 757 731 220 294 283 0 1095 March 6 2,475 2,502 2,486 758 836 785 286 346 309 0 1057 March 7 2,490 2,506 2,498 807 833 814 312 342 321 0 993 March 8 2,502 2,511 2,507 803 817 808 307 317 311 0 967 March 9 2,490 2,506 2,500 815 857 837 314 342 330 0 928 March 10 2,493 2,504 2,499 857 943 886 341 360 348 0 910 March 11 1,615 2,674 1,844 943 1,057 989 83 362 199 0 46 March 12 1,461 1,615 1,530 1,005 1,047 1,038 19 83 47 0 0 March 13 1,363 1,461 1,409 1,045 1,048 1,046 1 19 6 0 0 March 14 1,292 1,363 1,327 1,048 1,054 1,051 1 3 2 0 0 March 15 1,236 j 1,292 1,263 1,054 1,059 1,057 3 5 4 0 0 March 16 1,189 1,236 1,212 1,059 1,064 1,062 4 5 5 0 0 March 17 1,148 1,189 1,168 1,064 1,069 1,067 5 6 6 0 0 March 18 1,112 1,148 1,130 1,069 1,075 1,072 6 6 6 0 0 Caelus Natural Resources Alaska, LLC Page 11 March 19 1,079 1,113 1,095 1,075 1,079 1 1,077 6 7 6 0 0 March 20 1,050 1,079 1,064 1,079 1,082 1,080 6 7 7 0 0 March 21 1,023 1,050 1,037 1,082 1,087 1,085 7 7 7 0 0 March 22 999 1,023 1,011 1,087 1,096 1,091 7 7 7 0 0 March 23 976 999 987 1,095 1,102 1,099 6 7 6 0 0 March 24 955 976 965 1,102 1,107 1,105 6 6 6 0 0 March 25 935 955 945 1,106 1,107 1,106 6 6 6 0 0 March 26 917 935 926 1,106 1,107 1,107 6 6 6 0 0 March 27 900 917 909 1,107 1,108 1,107 6 6 6 0 0 March 28 884 901 892 1,108 1,108 1,108 6 6 6 0 0 March 29 869 885 877 1,108 1,109 1,109 6 6 6 0 0 March 30 855 869 862 1,109 1,110 1,109 6 6 6 0 0 March 31 854 855 855 1,110 1,110 1,110 6 6 6 0 0 April 1 828 841 835 1,110 1,111 1,111 6 6 6 0 0 April 2 816 828 822 1,111 1,112 1,111 6 6 6 0 0 April 3 804 816 810 1,111 1,112 1,112 6 6 6 0 0 April 4 793 804 799 1,044 1,112 1,094 5 6 6 0 0 April 5 782 793 787 992 1,044 1,013 5 6 5 0 0 April 6 771 782 777 969 992 980 6 6 6 0 0 April 7 761 771 766 953 969 960 6 7 6 0 0 April 8 752 762 757 942 953 948 7 7 7 0 0 April 9 743 752 747 932 942 937 7 7 7 0 0 April 10 734 743 738 922 932 927 7 7 7 0 0 April it 725 734 730 914 922 918 7 8 8 0 0 April 12 717 725 721 905 914 909 7 8 7 0 0 April 13 710 717 713 897 905 901 7 8 7 0 0 April 14 702 710 706 889 897 893 8 8 8 0 0 April 15 695 702 698 882 890 886 8 8 8 0 0 April 16 688 695 691 876 882 879 8 8 8 0 0 April 17 681 688 685 869 876 872 8 8 8 0 0 April 18 675 681 678 862 869 866 8 8 8 0 0 April 19 668 675 671 856 862 859 8 8 8 0 0 April 20 662 668 665 849 856 852 8 8 8 0 0 April 21 656 662 659 843 849 846 8 9 8 0 0 April 22 650 656 653 836 843 839 6 9 7 0 0 April 23 644 650 647 830 836 833 6 7 6 0 0 April 24 639 644 642 824 830 827 7 7 7 0 0 April 25 633 639 636 819 825 822 7 8 7 0 0 April 26 628 633 631 813 819 816 7 8 8 0 0 April 27 623 628 626 807 813 810 8 8 8 0 0 April 28 618 623 621 802 808 805 8 8 8 0 0 April 29 614 619 616 797 802 800 8 9 8 0 0 April 30 609 614 611 792 797 794 9 9 9 0 0 Caelus Natural Resources Alaska, LLC Page 12 May 1 604 609 607 787 792 789 9 9 9 0 0 May 2 600 605 602 782 787 784 9 9 9 0 0 May 3 595 600 597 777 782 779 9 9 9 0 0 May 4 591 595 593 773 777 775 9 10 9 0 0 May 5 587 591 589 768 773 770 9 10 10 0 0 May 6 583 587 585 763 768 766 10 10 10 0 0 May 7 577 835 591 749 783 759 10 10 10 0 0 May 8 200 614 580 730 749 739 9 10 10 0 0 May 9 570 574 572 728 733 731 9 9 9 0 0 May 10 565 570 568 724 729 726 9 9 9 0 0 May 11 561 566 563 720 724 722 9 9 9 0 0 May 12 557 562 559 716 720 718 9 9 9 0 0 May 13 553 558 555 713 716 714 9 9 9 0 0 May 14 550 553 552 709 713 711 9 9 9 0 0 May 15 546 550 548 706 709 707 9 9 9 0 0 May 16 543 546 545 702 706 704 9 9 9 0 0 May 17 539 543 541 699 702 700 9 9 9 0 0 May 18 536 540 538 695 699 697 9 9 9 0 0 May 19 533 536 534 692 695 694 9 9 9 0 0 May 20 530 533 531 689 692 690 9 9 9 0 0 May 21 526 530 528 685 689 687 9 9 9 0 0 May 22 523 526 525 682 685 684 9 9 9 0 0 May 23 520 523 522 679 682 681 9 9 9 0 0 May 24 517 520 519 676 679 678 9 9 9 0 0 May 25 514 517 516 673 676 674 9 9 9 0 0 May 26 511 514 513 670 673 672 9 10 9 0 0 May 27 509 511 510 667 670 669 9 10 9 0 0 May 28 506 509 507 664 667 666 9 10 9 0 0 May 29 503 506 504 661 665 663 9 9 9 0 0 May 30 500 503 502 659 662 660 9 9 9 0 0 May 31 498 500 499 656 659 658 9 10 10 0 0 June 1 495 498 496 653 656 655 9 10 9 0 0 June 2 494 1,495 555 599 686 641 9 19 11 0 0 June 3 550 562 555 638 648 645 10 it 10 0 0 June 4 545 550 548 647 649 648 10 10 10 0 0 June 5 542 545 544 644 647 646 10 10 10 0 0 June 6 539 542 541 641 644 643 30 10 10 0 0 June 7 536 540 538 639 641 640 10 10 10 0 0 June 8 534 537 535 636 639 637 10 10 10 0 0 June 9 533 1,840 1,439 636 998 802 10 540 306 0 1,269 June 10 1,760 1,939 1,855 998 1,131 1,068 540 605 579 0 2,012 June it 964 2,093 1,807 1,036 1,354 1,175 352 644 554 0 1,393 June 12 1,983 2,137 2,043 1,270 1,424 1,343 585 676 630 0 2,118 Caelus Natural Resources Alaska, LLC Page 13 June 13 895 2,075 1,313 1,208 1,429 1,326 213 677 437 0 453 June 14 809 2,032 1,162 1,133 1,432 1,189 139 521 229 0 463 June 15 2,032 2,219 2,145 1,434 1,710 1,654 522 671 654 0 1,843 June 16 1,272 2,501 1,854 1,496 1,839 1,699 292 719 563 0 748 e FJun 17 1,042 1,272 1,134 1,305 1,496 1,386 116 292 186 0 0 e 18 941 1,042 987 1,208 1,305 1,253 51 116 79 0 0 June 19 881 941 910 1,141 1,208 1,172 20 51 33 0 0 June 20 837 881 858 1,092 1,141 1,116 9 21 13 0 0 June 21 803 837 819 1,050 1,092 1,070 5 9 6 0 0 lune 22 775 803 788 1,010 1,050 1,030 3 5 4 0 0 June 23 752 775 763 976 1,010 993 3 3 3 0 0 June 24 732 752 742 948 976 962 3 4 3 0 0 June 25 715 732 723 925 948 936 4 4 4 0 0 June 26 699 715 707 904 925 914 4 5 5 0 0 June 27 685 699 692 886 904 895 5 5 5 0 0 June 28 673 686 679 870 886 878 5 6 5 0 0 June 29 662 673 667 856 870 863 6 6 6 0 0 June 30 652 662 6S7 842 8S6 849 6 6 6 0 0 July 1 642 652 647 831 842 837 6 7 6 0 0 July 2 633 642 638 821 831 826 7 7 7 0 0 July 3 624 633 629 811 821 816 7 7 7 0 0 July 4 617 624 620 802 811 806 7 7 7 0 0 July 5 609 617 613 794 802 798 6 7 6 0 0 July 6 603 609 606 787 794 790 6 7 6 0 0 July 7 596 603 600 780 787 783 7 7 7 0 0 July 8 590 597 593 773 780 776 7 8 7 0 0 July 9 585 590 588 766 773 769 6 8 7 0 0 July 10 579 585 582 761 766 763 6 6 6 0 0 July 11 574 579 577 755 761 758 6 6 6 0 0 July 12 569 S74 572 751 756 753 6 6 6 0 0 July 13 564 569 567 746 751 748 6 7 6 0 0 July 14 559 564 562 742 746 744 7 7 7 0 0 July 15 555 560 557 737 742 739 7 8 8 0 0 July 16 551 555 553 732 737 735 7 8 7 0 0 July 17 546 551 549 728 732 730 7 7 7 0 0 July 18 543 547 545 724 728 726 7 7 7 0 0 July 19 539 543 541 720 724 722 7 8 8 0 0 July 20 535 539 537 716 720 718 6 8 7 0 0 July 21 531 S35 533 712 716 714 6 6 6 0 0 July 22 528 531 529 708 712 710 6 6 6 0 0 July 23 524 528 526 704 708 706 6 6 6 0 0 July 24 521 524 522 700 704 702 6 6 6 0 0 July 25 518 521 519 697 700 699 6 6 6 0 0 Caelus Natural Resources Alaska, LLC Page 14 July 26 514 518 516 693 697 695 6 6 6 0 0 July 27 511 515 513 690 693 692 6 6 6 0 0 July 28 508 512 510 687 690 689 6 7 6 0 0 July 29 505 509 507 684 687 686 7 8 7 0 0 July 30 503 506 504 681 684 683 8 8 8 0 0 July 31 500 503 501 678 681 679 7 8 8 0 0 August 1 497 500 499 675 678 676 8 8 8 0 0 August 2 495 498 496 671 675 673 8 8 8 0 0 August 3 492 495 493 668 671 670 8 8 8 0 0 August 4 489 492 491 665 668 667 7 8 8 0 0 August 5 487 490 488 663 665 664 8 8 8 0 0 August 6 485 487 486 659 663 661 6 8 7 0 0 August 7 469 1,628 879 76 659 454 0 472 123 0 385 August 8 1,502 1,740 1,606 389 443 416 462 500 480 0 741 August 9 1,511 1,940 1,828 386 733 542 467 596 548 0 919 August 10 1,938 2,041 1,986 734 831 795 596 673 643 0 980 August 11 2,038 2,129 2,072 782 820 796 612 652 627 0 978 August 12 2,129 2,193 2,155 813 882 866 591 612 603 0 970 August 13 1,331 2,210 2,065 713 874 821 396 591 535 0 776 August 14 2,143 2,274 2,235 785 1,258 1,080 485 592 552 0 1,009 August 15 2,251 2,279 2,267 1,258 1,441 1,374 539 559 551 0 957 August 16 2,271 2,309 2,279 1,427 1,458 1,434 546 569 552 0 949 August 17 2,305 2,339 2,329 421 1,475 931 445 579 517 0 994 August 18 2,325 2,341 2,331 448 489 461 441 479 453 0 982 August 19 2,341 2,363 2,353 460 517 495 452 499 481 0 966 August 20 2,347 2,362 2,356 485 516 499 468 497 481 0 963 August 21 2,350 2,389 2,375 457 485 470 441 468 455 0 941 August 22. 2,283 2,394 2,381 443 461 452 412 441 425 0 914 August 23 1,278 2,435 1,611 321 450 361 103 416 239 0 144 August 24 1,181 2,329 1,713 311 409 353 51 350 178 0 517 August 25 1,743 2,416 2,343 367 515 451 311 432 383 0 888 August 26 2,416 2,450 2,433 515 550 529 417 429 424 0 892 August 27 2,435 2,452 2,445 550 621 594 424 451 443 0 845 August 28 2,091 2,448 2,427 578 629 607 417 453 437 0 763 August 29 2,427 2,448 2,438 610 631 619 435 455 443 0 746 August 30 2,434 j 2,454 2,446 586 610 601 412 435 426 0 735 August 31 2,449 2,467 2,459 583 599 592 408 423 416 0 713 September 1 2,456 2,467 2,463 584 599 590 408 423 414 0 722 September 2 2,443 2,458 2,448 558 584 566 384 408 391 0 760 September 3 2,440 2,453 2,448 558 571 562 383 394 386 0 761 September 4 2,441 2,459 2,453 560 573 566 383 393 388 0 751 September 5 2,451 2,465 2,460 556 568 563 377 388 383 0 736 Caelus Natural Resources Alaska, LLC Page 15 September 6 2,458 2,514 2,504 555 569 560 375 386 379 0 757 September 7 1,921 2,539 2,479 521 638 578 328 392 383 0 708 September 8 2,539 2,556 2,548 638 756 707 388 407 404 0 726 September 9 2,547 2,563 2,558 746 759 754 388 407 398 0 734 September 10 2,540 2,556 2,550 733 746 737 376 388 380 0 722 September 11 2,540 2,560 2,550 727 750 736 368 387 376 0 710 September 12 2,548 2,561 2,555 730 750 737 367 387 374 0 716 September 13 2,529 2,560 2,552 730 761 735 366 392 370 0 706 September 14 2,557 2,571 2,563 738 768 750 368 399 380 0 712 September 15 2,546 2,572 2,567 736 753 745 362 379 371 0 632 September 16 2,540 2,574 2,559 720 758 731 347 382 357 0 685 September 17 2,566 2,573 2,569 734 758 745 357 381 367 0 702 September 18 2,551 2,573 2,566 725 771 744 347 388 364 0 662 September 19 1,912 2,575 2,495 713 863 774 281 381 355 0 632 September 20 2,573 2,592 2,583 862 883 874 373 389 383 0 670 September 21 2,572 2,591 2,581 852 882 872 359 388 378 0 659 September 22 2,580 2,593 2,590 838 852 843 346 359 351 0 649 September 23 1,876 2,589 2,465 786 840 828 242 348 323 0 552 September 24 2,574 2,592 2,583 831 850 839 321 341 329 0 625 September 25 2,577 2,592 2,587 850 895 873 331 346 337 0 615 September 26 2,583 2,600 2,594 891 1,253 1,036 331 369 348 0 621 September 27 2,582 2,604 2,590 1,253 1,275 1,270 353 369 360 0 622 September 28 2,585 2,605 2,598 1,267 1,273 1,271 344 353 349 0 614 September 29 2,598 2,610 2,606 1,261 1,268 1,265 338 345 342 0 616 September 30 2,597 2,613 2,607 1,257 1,261 1,260 334 338 337 0 608 October 1 2,600 2,615 2,611 1,245 1,257 1,250 322 334 327 0 607 October 2 2,533 2,611 2,589 1,240 1,281 1,253 313 353 327 0 572 October 3 2,588 2,623 2,608 1,254 1,266 1,258 326 337 330 0 594 October 4 2,597 2,613 2,606 1,254 1,264 1,256 326 335 328 0 597 October 5 2,601 2,609 2,604 1,251 1,264 1,255 322 334 326 0 605 October 6 2,594 2,609 2,604 1,251 1,259 1,254 320 328 324 0 605 October 7 2,603 2,618 2,613 1,253 1,262 1,257 322 329 325 0 604 October 8 1,987 2,622 2,553 1,222 1,301 1,260 264 332 320 0 549 October 9 2,604 2,635 2,621 1,301 1,327 1,321 329 340 334 0 600 October 10 2,617 2,634 2,626 1,315 1,334 1,320 326 343 331 0 584 October 11 1 5,013 2,568 1 4,682 1,322 0 1,996 338 0 595 October 12 2,587 2,611 2,603 1,314 1,325 1,320 320 331 326 0 601 October 13 2,588 2,609 2,599 1,310 1,331 1,322 316 335 327 0 601 October 14 2,597 2,615 2,610 1,304 1,333 1,317 310 337 323 0 615 October 15 2,602 2,615 2,613 1,310 1,350 1,334 315 351 338 0 596 October 16 1,674 2,609 2,055 1,282 1,429 1,330 124 338 211 0 216 October 17 2,454 2,520 2,502 1,429 1,570 1,528 239 318 307 0 542 Caelus Natural Resources Alaska, LLC Page 16 October 18 1,851 2,584 2,455 1,566 1,706 1,619 247 339 306 0 523 October 19 2,579 2,603 2,591 1,691 1,752 1,725 315 368 344 0 585 October 20 2,595 2,610 2,606 1,752 1,825 1,784 368 432 395 0 576 October 21 1,874 2,613 2,420 1,781 2,024 1,866 297 444 400 0 411 October 22 1,695 2,583 1,967 1,234 2,042 1,701 144 431 249 0 64 October 23 1,638 1,789 1,705 1,717 1,803 1,783 82 144 110 0 0 October 24 1,551 1,639 1,592 1,802 1,804 1,803 50 82 64 0 0 October 25 1,493 1,657 1,524 1,575 1,805 1,645 10 50 22 0 0 October 26 1,445 1,493 1,468 1,571 1,597 1,588 3 10 6 0 0 October 27 1,403 1,445 1,424 1,564 1,571 1,566 3 5 4 0 0 October 28 1,367 1,403 1,385 1,567 1,569 1,568 5 6 5 0 0 October 29 1,336 1,367 1,352 1,569 1,571 1,570 5 6 5 0 0 October 30 1,309 1,336 1,323 1,571 1,573 1,572 5 5 5 0 0 October 31 1,285 1,310 1,297 1,573 1,575 1,574 5 5 5 0 0 November 1 1,261 1,285 1,273 1,575 1,576 1,575 4 6 5 0 0 November 2 1,241 1,262 1,251 1,576 1,578 1,577 6 6 6 0 0 November 3 1,221 1,241 1,231 1,577 1,579 1,578 6 6 6 0 0 November 4 1,202 1,221 1,210 1,579 1,579 1,579 6 6 6 0 0 November 5 1,183 1,202 1,192 1,579 1,580 1,580 6 6 6 0 0 November 6 1,167 1,183 1,175 1,580 1,581 1,581 6 6 6 0 0 November 7 1,150 1,167 1,159 1,581 1,582 1,581 5 6 6 0 0 November 8 1,134 1,151 1,142 1,581 1,582 1,582 5 6 6 0 0 November 9 1,120 1,134 1,127 1,582 1,583 1,583 6 6 6 0 0 November 10 1,106 1,120 1,113 1,583 1,584 1,583 6 6 6 0 0 November 11 1,092 1,106 1,099 1,583 1,584 1,584 5 6 6 0 0 November 12 1,080 1,093 1,086 1,584 1,585 1,584 5 6 5 0 0 November 13 1,066 1,080 1,073 1,585 1,585 1,585 5 6 5 0 0 November 14 1,055 1,066 1,061 1,585 1,586 1,585 5 6 6 0 0 November 15 1,043 1,055 1,049 1,586 1,586 1,586 5 7 5 0 0 November 16 1,032 1,043 1,037 1,586 1,586 1,586 5 8 6 0 0 November 17 1,021 1,032 1,026 1,586 1,587 1,587 6 7 6 0 0 November 18 1,010 1,021 1,016 1,587 1,588 1,588 4 7 6 0 0 November 19 1,000 1,011 1,005 1,588 1,588 1,588 3 5 4 0 0 November 20 990 1,000 996 1,588 1,589 1,588 2 4 3 0 0 November 21 981 991 986 1,587 1,588 1,587 1 2 1 0 0 November 22 971 981 976 1,587 1,589 1,588 1 2 2 0 0 November 23 962 971 967 1,588 1,589 1,589 2 2 2 0 0 November 24 954 962 958 1,589 1,589 1,589 1 3 2 0 0 November 25 945 955 950 1,589 1,590 1,590 1 3 2 0 0 November 26 936 945 941 1,589 1,590 1,589 1 2 2 0 0 November 27 928 936 932 1,589 1,590 1,590 1 2 1 0 0 November 28 920 928 924 1,590 1,590 1,590 0 1 1 0 0 November 29 913 920 917 1,590 1,590 1,590 0 1 0 0 0 Caelus Natural Resources Alaska, LLC Page 17 November 30 906 913 909 1,590 1,590 1,590 0 1 1 0 0 December 1 898 905 901 1,590 1,596 1,591 0 47 2 0 0 December 2 891 898 894 1,590 1,591 1,590 0 0 0 0 0 December 3 883 891 887 1,590 1,591 1,590 0 0 0 0 0 December 4 876 883 879 1,590 1,591 1,591 0 0 0 0 0 December 5 869 876 873 1,591 1,591 1,591 0 0 0 0 0 December 6 862 869 866 1,591 1,591 1,591 0 0 0 0 0 December 7 856 862 859 1,591 1,598 1,593 0 81 17 0 0 December 8 850 856 853 1,595 1,596 1,595 43 43 43 0 0 December 9 814 3,057 1,094 -7 3,006 1,249 33 132 45 0 0 December 10 851 3,057 1,337 -3 3;016 1,646 36 137 47 0 0 December 11 430 1,980 1,368 437 1,804 1,533 45 414 171 0 453 December 12 1,981 2,152 2,088 571 918 760 310 426 379 0 841 December 13 2,137 2,204 2,170 918 1,179 995 426 460 438 0 841 December 14 2,144 2,319 2,250 1,180 1,692 1,532 460 528 503 0 820 December 15 2,319 2,366 2,344 1,692 1,741 1,713 528 530 529 0 825 December 16 2,366 2,400 2,384 404 1,762 954 358 530 430 0 788 December 17 2,400 2,424 2,412 418 435 432 351 365 363 0 759 December 18 2,396 2,408 2,401 393 418 397 333 351 336 0 752 December 19 2,408 2,423 2,417 391 409 400 332 346 339 0 735 December 20 2,420 2,432 2,426 409 423 417 346 358 353 0 727 December 21 2,326 2,440 2,411 362 424 389 304 359 328 0 605 December 22 2,439 2,456 2,449 381 451 403 321 388 342 0 685 December 23 2,456 2,463 2,460 350 382 376 298 321 317 0 676 December 24 2,462 2,467 2,464 250 350 272 205 298 224 0 669 December 25 1,753 2,501 2,369 231 343 263 125 219 192 0 642 December 26 2,501 2,537 2,525 343 663 497 195 229 214 0 592 December 27 2,527 2,535 2,532 651 662 657 220 229 225 0 562 December 28 2,533 2,632 2,590 646 719 667 215 276 237 0 704 December 29 2,628 2,640 2,634 712 1,046 769 254 308 272 0 758 December 30 2,581 2,638 2,632 1,047 1,375 1,328 308 350 331 0 746 December 31 2,584 2,634 2,602 1,353 1,376 1,362 332 1 352 340 0 877 1LY,377 Caelus Natural Resources Alaska, LLC Page 18 Notes for Highlighted Dates Above: WW Morning report 1/13 MIRU HES Slickline w/.125 wire. Drifted w/3.83" gauge ring to SVLN @ 2,075' SLM. Pulled 4.5" FXE SSSV from SVLN @ 2,075' SLM. Drifted w/4.5" BLB & 3.80" gauge ring but was unable to work past 2,850'slm. MIRU LRS to tubing and begin Brush & Flush operations. Brush & Flush tubing w/4.5" BLB & 3.80" gauge ring to 4,850'slm. LRS pumped a total of 93 bbls of diesel (6100'). Decision made to lay crews down forthe night. Plan forward is to continue Brush & Flush operations @ 4,850' slm with LRS support. WW Morning report 1/14 Continue Tx IA Diagnostics. Brush & Flush tubing w/4.5" BLB & 3.80" gauge ring to 9,202' slm while LRS pumped hot diesel. Set4.5" PXN plug in XN nipple @ 9,202' sim. MIT-Tubing passed on first test. MIT-IA passed on first test. Made one attempt to pull Dummy GLV from GLM # 2, was unable to locate. Slickline crew layed down forthe night. Plan forward is to pull 1" Dummy GLV from GLM # 2, set 1" Dummy GLV with extended packing in GLM # 2, and conduct MIT-Tbg & MIT-IA. Will change up KOTfrom 4.5" OK-6to 4.5" OK-1which has a more aggressive locatorfinger. WW Morning report 1/15 Continue Tx IA Diagnostics. Pulled 1" Dummy GLV from GLM # 2. Set 1" Dummy GLV w/extended packing in GLM # 2. MIT-Tubing to 3000 psi, test passed first attempt. MIT-IA to 3000 psi, test passed first attempt. Discussed plan forward w/Anchorage team. Pulled 1' Dummy GLV from GLM# 1. Set I" Dummy GLV w/extended packing in GLM # 1. LRS pressured tubing up to 3000 psi. HES Slickline crew layed down forthe night. Left 3000 psi on tubing & monitored through the night. Plan forward is to MIT-IA to 3000 psi for 30 minutes then relay results to Anchorage team. Ops Morning report 1/18 T/S and reparied leaky Graylok connection on T46i. Ops Morning report 2/8 Fluid packed the IAs for upcoming MITs on wells N07i, K38i and T46i. Ops Morning report 2/9 Completed MITon T46 and it passed. OTM Charts 9/27 for 10/11 POI to evaluate Tx1A Communcation OTM Charts for 10/25 for 10/21 Shut in due to TxIA communication Ops Morning report 10/22 FP'd T46i with 5bbls McOH and 36bbls diesel. Ops Morning report 12/9 MITs on T46i WW Morning report 12/10 Completed well handover from Ops to Wells. MIRU HES Slickline w/.125 wire. Drifted w/3.83" gauge ring to SVLN @ 2,075' SLM. Pulled 4.5" FXE SSSV from SVLN @ 2,075' SLM. LRS performed MIT-IA to 3000 psi for 30 minutes. MIT-IA passed first attempt. Lost 70 psi the first 15 min, lost 12 psi the last 15 min. Drifted w/4.5" BLB & 3.80" gauge ring to XN nipple @ 9,202'slm. Set 4.5" Cat Standing Valve in XN nipple @ 9,202'sim. LRS performed MIT- Tubing to 3050 psi for 30 minutes. MIT-T passed first attempt. Lost 45 psi the first 15 min, lost 22 psi the last 15 min. Pulled 1" Dummy GLV (BL, Ext pkg) from GLM # 2 @ 6,973'sim. Inspect valve on surface. Upper & lower packing is torn. Appears packing was damaged during setting operations. Set 1" Dummy GLV (BL, Oversized Pkg 1.025" -1.058") in GLM #2 @ 6,973'slm. Secured well, Slickline crew layed down for the night. Caelus Natural Resources Alaska, LLC Page 19
