Potential PM2.5 and CPM Pitfalls in Permitting, Testing, and Compliance
Luis Romualdez_CRC_Oxy
1. UPDATE – CRC/OXY HIGHLIGHTS
California Resources
Corporation• Greater Elk Hills Area
• Luis Romualdez, Chief Reservoir Engineer
2. GEHA ADM Supervisors:
• David George ~ 1.5 years
• Ken Haney ~ 0.6 years
2015 Chief RE Mandate:
• M.O.S.T. = Mentoring (20%), Optimization (30%), Surveillance (40%), Training (10%)
2013-2015 Highlights (numbered as per Attachments):
1) Streamlined and successfully implemented the GEHA Surveillance Process, critical in
surpassing the Elk Hills production target to date by about 5,000 boe/d
2) Assisted the Stevens RMT in booking an additional 8–10 MMBOE of proven reserves for the
Stevens 31S
3) Instrumental in determining the best methodology to book proven reserves for the contentious
ESOZ reservoir as corroborated by Central Reserves’ final decision (i.e., by fault block with
maximum b=1)
4) Successfully procured and implemented the 3DSL streamline waterflood re-alignment program
which has resulted in success at Yowlumne and many more CRC opportunities for
“incremental oil at zero cost”
5) Leading the initiative for “poor boy” EOR at CRC such as microbial, micro-emulsion and
electric heating.
6) Successfully implemented the RE development and mentorship programs
Achievement Highlights: 2013-2015
3. (1) 2015 GEHA Surveillance Process
Exception Based
Surveillance
(Losers/Gainers)
Operational ? ACTION
Operations
Engineer
Review
Resolved?
Scheduled
Operational
Checklist
Scheduled
Reservoir
Surveillance
ACTION
ACTION
Ongoing
Base/Wedge
Surveillance
Reservoir?
Forward Exception Well List
to Exception Surveillance
(Field Operations)
Well List
(Region/Strip/Pattern)
Well List
(PDP FC Deviation)
FIELD OPERATIONS
(daily / weekly)
OPERATIONS ENGINEER
(weekly / monthly)
RESERVOIR
MANAGEMENT TEAM
(monthly / yearly)
Y
N
Y
N
N
Y
4. (2) 31S Shales - PUD Location Map
(2014)
4
34S Area (NAB)
32S Area (NABCD)
West Half Flanks (NAB)
West Half Crest (NAB)
36S Area (NABCD)
• Analog wells are selected based on geologic similarity and vintage in areas with
similar producing characteristics
• Generally PUD/ P2 / P3 designation based upon one/two/three offsets away,
respectively, from active wells with rates that would support capital investment
Shales
RESERVE CATEGORY OPEN CLOSE
P1 77 54
P2 13 25
P3 1 10
C1 0 0
C2 62 69
C3 27 27
Shales TOTAL 180 185
Shales Transfers to PDP
RESERVE CATEGORY Number Drilled
P1 18
P2 3
P3 0
C1 0
C2 17
C3 0
Shales TOTAL 38
21
3
11
15
4
5. ESOZ PDP Estimation Methods
Method
Name Forecast Granularity Forecast Method
Hyperbolic Factor
Limitations
Base Well Set Used to
Define Initial Decline
Rate
Gross PDP Base
Reserves
(MMBOE)
Net PDP Base
Reserves
(MMBOE)
Reasonable
Certainty
Case 0 Fault Block Oil Rate vs. Time b ≤ 2 YE2009 99.97 69.99
Case 1 Fault Block Oil Rate vs. Time b ≤ 1 YE2009 49.66 34.77
Case 2 Individual Well Oil Rate vs. Time N/A N/A 49.74 34.82
Case 3 Fault Block Log(GOR) vs. Cumulative Oil N/A YE2013 73.90 51.73
Case 4 Fault Block Oil Rate vs. Cumulative Oil N/A YE2013 52.88 37.02
Case 5 Full Field Log(GOR) vs. Cumulative Oil b = 1 YE2013 83.75 58.63
Case 6 Full Field Log(GOR) vs. Cumulative Oil b = 1 YE2011 48.95 34.27
Case 7 Fault Block Oil Rate vs. Time b = 1 YE2013 90.42 63.30
(3) ESOZ PDP Results – 2014 Conclusions
**
*All volumes shown are reported as of YE2014
** The volumes are reasonable. This method assumes that all gas is being produced by the YE2011 base, which is an unreasonable assumption.
6. 6
(4) RESULTS OF OPTIMIZATION (YOWLUMNE FIELD)
Lost one of main injectors
Start Optimizing Target Rates
Provide April Target Rates
Lost three producers
(Surface and
Downhole issues)
DailyProduction(BOEPD)
3.5 % monthly
exponential
Decline
2.3 % monthly
exponential Incline
