2025 Exam Comments

 Exam Availability: Once a Year Next Test Date: October 8, 2025

If anyone would like some help or free advice before October, feel free to reach out to me. I like to discuss what's going on with the new generation. I only do it when I want to, so it's no bother at all. 

https://ncees.org/exams/pe-exam/petroleum/

Look forward to the first comment of 2025!

2024 PE Exam Comments

Congrats to all those who took the 2024 exam. I truly enjoy reading your comments. 

Any comments you make can help future test-takers. And of course suggestions for blog/Guidebook/Companion improvements are always welcome and appreciated.

Please remember the blog rule: specific prior PE Exam questions cannot be discussed. General topics, resource suggestions, and testing techniques only please. Try not to discuss specific problems from prior exams, such as comments like: "...several of the drilling questions with probability...” it too specific as per the test-writers. Thanks, folk! 

There is a delay between comment submission and when it appears; please be patient. 

NOTE: The 2025 Exam: Exam Availability: Once a Year Next Test Date: October 8, 2025

If anyone would like some help or advice, feel free to reach out to me. I like to discuss what's going on with the new generation and only when I want to, so it's no bother at all. 

https://ncees.org/exams/pe-exam/petroleum/

2023 PE Exam Comments

To all who were bold enough congratulations on taking the 2023 exam!  

Any comments you take the time to make can help future test-takers prepare. And of course suggestions for blog/Guidebook/Companion improvements are always welcome and appreciated. I enjoy hearing from all. 

Please remember the blog rule: specific prior PE Exam questions cannot be discussed. General topics, resource suggestions, and testing techniques only please. Try not to discuss specific problems from prior exams, such as comments like: "...several of the drilling questions with probability...” it too specific as per the test-writers. Thanks, folk! 

There is a delay between comment submission and when it appears; please be patient. 

2022 PE Exam Comments

The 2022 exam is now in the past! 

Any comments you test-takers have will help future test-takers to prepare. And any suggestions for blog/Guidebook/Companion improvements are always welcome and appreciated. I really enjoy hearing from everyone. 

Please remember the blog rule: specific prior PE Exam questions, in whole or in part, cannot be discussed. General topics, resource suggestions, and testing techniques only please. Try not to "cross the line" into discussing specific problems from prior exams, such as comments like: "...several of the drilling questions with probability...” it too specific as per the test-writers. Thanks, folk! 

There is a delay between comment submission and when it appears; please be patient. 

11-7-22 UPDATE: Thanks everyone for the excellent comments!

If you didn't pass his year and need some help prepping for 2023, let me know in the next few weeks and I'll try to set up a free class or two by Zoom or email. Sometimes all it takes is some basic advice. I do these classes just to keep mentally 'up-to-date', so don't worry about putting me out.

Economics: 2021 #31

A company has two good but highly speculative opportunities to invest in, gas field A and oil field B, yet only enough capital to invest in one due to a stiff interest rate of 15% for both. The investments and expected cash flows are below. Which alternative should be selected based on NPV analysis?
A) Investment A; NPV of A >$50,000 more than “B”
B) Investment A; NPV of A <$50,000 more than “B”
C) Investment B; NPV of B <$50,000 more than “A”
D) Investment B; NPV of B >$50,000 more than “A”
A and B
Initial invest: $200M and $300M
Annual revenue: $100M and $150M
Annual expense: $10M and $25M
Invest life (yrs): 7 and 7
Salvage Value: $50M and $175M

Water Intrusion: 2021 #30

Which mechanisms of water intrusion into oil wells are relatively easily controlled (select four only):
__ Watered-out layer without crossflow.
__ Fractures between injector and producer.
__ Moving oil/water contact.
__ Coning.
__ Cusping.
__ Casing leaks.
__ Edge water from poor areal sweeps.
__ Gravity segregated layer in a thick reservoir layer with high-vertical permeability.
__ Channel flow behind the casing from primary cementing that does not isolate water-bearing zones from the pay zone.
__ Fractures or faults from behind the water zone.

A fairly straighforward problem; you will either know it or you won't (depending on how well read or experienced one is). I'll update this problem answer later, to let the problem "sink in" and become ingrained in your mind. Remember, there are a dozen ways this probllem could be asked, so one must have a true understanding if it to be safe!

 X Watered-out layer without crossflow (HS4 P381).
__ Fractures between injector and producer (HS4 P381).
 X Moving oil/water contact (HS4 P381).
__ Coning (HS4 P381).
__ Cusping (HS4 P381).
 X Casing leaks (HS4 P381).
__ Edge water from poor areal sweeps (HS4 P381).
__ Gravity segregated layer in a thick reservoir layer with high-vertical permeability (HS4 P381).
 X Channel flow behind the casing from primary cementing that does not isolate water-bearing zones from the pay zone (HS4 P381).
__ Fractures or faults from behind the water zone (HS4 P381).

2021 PE Exam Comments

2021 is history. Comment away! Suggestions for blog/Guidebook/Companion improvements are always welcome and appreciated. I enjoy hearing from all. 

Please remember the blog rule: prior PE Exam questions, in whole or in part, will NOT be discussed. General topics, resource suggestions, and testing techniques only. Please don't "cross the line" by discussing specific problems from prior exams. Comments like: "...several of the drilling questions with probability...” is crossing the line. Thanks, folk! 

There will be a delay between comment submission and when it appears; please be patient.

Pumping: 2021 #29

A casing string is to be cemented at 10,000 ft in a well containing 10-lbm/gal mud, which will be displaced from the annulus by 500 ft of 8 lbm/gal mud flush, 1,500 ft of 12.5 lbm/gal filler cement, and 1,000 ft of 16.5 lbm/gal cement. The pump pressure (Mpsig) required to completely displace the cement from the casing with 9-lbm/gal brine is closest to: A) 1; B) 1.1; C) 1.2; D) 1.3.

Solution:
10000-500-1500-1000 = 7000 ft 9-lbm/gal.
0.052*((500*8)+(1500*12.5)+(1000*16.5)+(10*7000))=5681psig.
10,000*9=4680 psig.
5946 – 4680=1001 psig, “A”.
(TS12 P186; GB 3 HYD 2; RG P41, P67).

Casing Design: 2021 #28

True statements about casing design include (select any that apply):
__ Wells without H2S are called “sweet”.
__ A mixture of water and carbon dioxide is very corrosive.
__ Casing grade C-90 was developed with special metallurgy to resist sulfide stress cracking.
__ Casing grade T-95 was developed with special metallurgy to resist sulfide stress cracking.
__ Typically, high temperatures and lower-stress states accelerate hydrogen embrittlement.
__ For sour service, tubular-material selection is based on minimum temperature, yield strength, manufacturing process, and application.
__ Gas systems are sour when the maximum pressure exceeds 265 psi and partial pressure of H2S is greater than 0.05 psi.
__ Multiphase systems are considered sour if the maximum gas/oil ratio is less than 5,000 scf/bbl and the maximum pressure exceeds 265 psi, and H2S partial pressure in the gas phase is greater than 0.05 psi.
__ Multiphase systems are considered sour if the maximum gas/oil ratio is less than 5,000 scf/bbl and the maximum pressure is less than 265 psi, and H2S partial pressure in the gas phase is greater than 10 psi.
__ Multiphase systems are considered sour if the maximum gas/oil ratio is less than 5,000 scf/bbl and the gas phase contains more than 15 H2S.

These types of questions come from Textbook Series and some are pretty detailed. Much of the information ia also in the Handbook Series. At a minimum, I would know the basics, and these these types of questions have been selected as such.

 X Casing is classified according to five properties: the manner of manufacture, steel grade, type of joints, length range, and the wall thickness unit weight (HS2 P288).
 X Wells without H2S are called “sweet” (TS12 P405).
 X A mixture of water and carbon dioxide is very corrosive (TS12 P405).
 X Casing grade C-90 was developed with special metallurgy to resist sulfide stress cracking (TS12 P405).
 X Casing grade T-95 was developed with special metallurgy to resist sulfide stress cracking (TS12 P405).
__ Typically, high[low] temperatures and lower[higher] stress states accelerate hydrogen embrittlement (TS12 P405).
 X For sour service, tubular-material selection is based on minimum temperature, yield strength, manufacturing process, and application (TS12 P406).
 X Gas systems are sour when the maximum pressure exceeds 265 psi and partial pressure of H2S is greater than 0.05 psi (TS12 P406).
 X Multiphase systems are considered sour if the maximum gas/oil ratio is less than 5,000 scf/bbl and the maximum pressure exceeds 265 psi, and H2S partial pressure in the gas phase is greater than 0.05 psi (TS12 P406).
 X Multiphase systems are considered sour if the maximum gas/oil ratio is less than 5,000 scf/bbl and the maximum pressure is less than 265 psi, and H2S partial pressure in the gas phase is greater than 10 psi (TS12 P406).
 X Multiphase systems are considered sour if the maximum gas/oil ratio is less than 5,000 scf/bbl and the gas phase contains more than 15 H2S (TS12 P406).

Casing Design: 2021 #27

The quotient of API burst resistance and the API collapse-pressure rating of a 20-in., 133 lbf/ft, K-55 casing (nominal wall thickness 0.635 in.) is closest to: A) 0.5; B) 1.0; C) 1.5; D) 2.0; E) 2.5; F) 3.0.

Pb=(0.875*2*55000*0.635)/20)=3056=3060 psi.
d/t=20/0.635=31.496.
F5=0.036 use Table 2.3 pg 56 J-55 (F5 is same as K-55).
Pcr=YS(Fr/(d/t))-F5.
Pcr=55000*((1.980/31.496)-0.036))=1493=1490 psi.
3060/1490=2.05, “D”.
(RG P55-56; TS12 P399, P402; GB 6 DTC 2).

Casing Design: 2021 #26

True statements about casing design include (select any that apply):
__ Casing is classified according to five properties: the manner of manufacture, steel grade, type of joints, length range, and the wall thickness (unit weight).
__ Oil country tubular goods (OCTG) include casing, tubing, and drillpipe but does not include line pipe.
__ Line pipe cannot be used in oil and gas wells below the surface.
__ The average cost of tubulars is typically more than 1/4 of the average cost of a completed well.
__ A well that will not encounter abnormal formation pore pressure gradients, lost-circulation zones, or salt sections may require only conductor casing and surface casing to drill to the objective for the well.
__ Surface-casing setting depths are usually from 3,000 to 9,000 ft into the sediments.
__ Liners are casing strings that do not extend to the surface but are suspended from the bottom of the next larger casing string.
__ Production liners are generally connected to the surface wellhead using a tieback casing string when the well is completed.
__ Casing is defined as tubular pipe cemented in the wellbore.
__ A casing grade code consists of a letter followed by a number which designates the minimum yield strength of the steel in thousands of psi.
__ The casing letter designation is used to distinguish between various tensile-strength requirements used on casing with the same minimum yield strength.
__ The casing letter designation is used to distinguish between different heat-treatment methods used on casing with the same minimum yield strength.

These long problems are tough. Read carefully but don't even bother to look in the provided Reference, because it won't be there. Add questions or comments in the comment box below.

 X Casing is classified according to five properties: the manner of manufacture, steel grade, type of joints, length range, and the wall thickness unit weight (HS2 P288).
__Oil country tubular goods (OCTG) include casing, tubing, line pipe, and drillpipe (TS12 P385).
__Line pipe is sometimes used in oil wells because it is available in larger sizes (TS12 P385).
__The average cost of tubulars is approximately 18% of the average cost of a completed well (TS12 P385).
 X A well that will not encounter abnormal formation pore pressure gradients, lost-circulation zones, or salt sections may require only conductor casing and surface casing to drill to the objective for the well (TS12 P385).
__ Surface-casing setting depths are usually from 300 to 5,000 ft into the sediments (TS12 P386).
 X Liners are casing strings that do not extend to the surface but are suspended from the bottom of the next larger casing string (HS2 P387).
 X Production liners are generally connected to the surface swellhead using a tieback casing string when the well is completed (TS12 P385).
__ Casing is defined as tubular pipe with an OD range of 4.5 to 20 in. (TS12 P388).
 X A casing grade code consists of a letter followed by a number which designates the minimum yield strength of the steel in thousands of psi (TS12 P388).
 X The casing letter designation is used to distinguish between various tensile-strength requirements used on casing with the same minimum yield strength (TS12 P388).
 X The casing letter designation is used to distinguish between different heat-treatment methods used on casing with the same minimum yield strength (TS12 P388).

Casing Design: 2021 #25

In problem #23 above, the deepest casing section should be run no higher than (ft):
A) 14,913
B) 14,923
C) 14,933
D) 14,943
E) 14,953

Find the csg with next lowest rating, max depth:
7755/(7800/15000)=14,913 (below neutral point), “A”.
References: (TS12 P430; GB 11 DCA 1; RG P41, P67).

Casing Design: 2021 #24

True statements about casing design include (select any that apply):
__ Conductor casing is the first string set below the structural casing.
__ Liner is a casing string that does extend back to the wellhead.
__ Tieback string is a casing string that provides additional pressure integrity from the liner shoe to the wellhead.
__ Tiebacks can be uncemented.
__ Tiebacks can be cemented.
__ Burst pressure conditions occur during well control operations and squeeze cementing.
__ Most oilfield tubulars experience collapse in the “plastic” and “transition” regimes.
__ For certain casing sizes, the threads are intended to be leak resistant when made up.
__ Buckling is typically a more critical design issue for production tubing than for casing.

The provided Reference Guide on the exam offers no help on word problems; hence, there is no escape from prior experience or study on these types of questions. Please provide comments or ask questions in the comment box below.

 X Conductor casing is the first string set below the structural casing (TS2 P287)
__ Liner is a casing string that does [not] extend back to the wellhead (TS2 P288).
__ Tieback string is a casing string that provides additional pressure integrity from the liner [top] to the wellhead (TS2 P288).
 X Tiebacks can be uncemented.
 X Tiebacks can be cemented.
 X Burst pressure conditions occur during well control operations and squeeze cementing.
 X Most oilfield tubulars experience collapse in the “plastic” and “transition” regimes.
__ For [all] casing sizes, the threads are [not] intended to be leak resistant.
 X Buckling is typically a more critical design issue for production tubing than for casing (TS2 P304).

Casing Design: 2021 #23

Design 7 in. production casing to be set in 11 lbm/gal mud in a vertical 15,000 ft well. Assume 10 lbm/gal pore pressure. Use three sections (minimum 2,000 ft each) based on pipe body performance properties. Design limits: 90M lbf overpull over buoyed casing weight...[see text]. What is the most cost-effective casing to use in the bottom of the hole?

A) 32 lbf, C-95
B) 29.0 lbf, C-110
C) 29.0 lbf, C-95
D) 26.0 lbf, C-95

Make sure you stay organized on this problem! Build a table of the needed information (provided in the problem or in the Reference on P41 and P67). Get be familiar with how the provided reference is organized; there is tons of data in a very small space and you need to be able to find and use it rapidly. Most importantly, the fomat is not overly similar to what you may be used to using. So here's our table:

Collapse (1.1) Burst (1.1) Tension (1.8).
23.0 lbf, C-95 3764 (4140) 6845 (7530) 486 (632).
26.0 lbf, C-95 5345 (5880) 7818 (8600) 552 (717).
29.0 lbf, C-95 7118 (7830) 8809 (9690) 618 (803).
32.0 lbf, C-95 8864 (9750) 9782 (10760) 681 (885).
29.0 lbf, C-110 7755 (8530) 10200 (11220) 715 (929).
Burst@surface=7780 psi.

Burst@TD: 7780+0.052*9*15000-0.052*10*15000=7000 psi.
Collapse surface=0 psi; Collapse@TD: 0.052*10*14000=7800 psi.
Neutral-Plane-BF=1-MW/65(P41)=1-11/65=0.846*15,000=12462’-NP-collapse-derate-above.
Section-1: TD-collapse-options>7800-is-8864 32 lbf, C-95, “A”.

References: (TS12 P430; GB 11 DCA 1; RG P41, P67).

This is a fairly tough problem. Remember, it's highly unlikely the design will be too complex, and your trick is to find the limiting factor as quickly as possible.

 

DCA: 2021 #22

True statements about decline curve analysis (DCA) include (select any that apply):
__ DCA is the most widely used method of forecasting future production from gas fields.
__ DCA is the most widely used method of forecasting future production from oil fields.
__ All real wells have hyperbolic decline.
__ DCA has few fundamental theoretical foundations.
__ Harmonic decline is a particular case of hyperbolic decline.
__ Exponential decline is a particular case of hyperbolic decline.
__ Hyperbolic decline is a particular case of exponential decline.
__ Hyperbolic decline is a particular case of harmonic decline.
__ Harmonic decline is a particular case of exponential decline.

Of course the provided Reference Guide will offer no assistance on word problems; you must know the material from prior experience or study. Feel free to ask questions in the comment box below.

 X DCA is the most widely used method of forecasting future production from gas fields (TS8 P170).
 X DCA is the most widely used method of forecasting future production from oil fields (TS8 P170).
 X All real wells have hyperbolic decline (TS8 P172).
 X DCA has few fundamental theoretical foundations (TS8 P172).
 X Harmonic decline is a particular case of hyperbolic decline (TS8 P172).
 X Exponential decline is a particular case of hyperbolic decline (TS8 P172).
__ Hyperbolic decline is not a particular case of exponential decline (TS8 P172).
__ Hyperbolic decline is not a particular case of harmonic decline (TS8 P172).
__ Harmonic decline is not a particular case of exponential decline. (TS8 P172).

DCA: 2021 #21

Well 24-7X was drilled and capable of 2,000 STB/D. However, production was immediately choked back to 900 STB/D from first production due to a combination of contractual and facility issues. In July of the fourth year...24-7X’s percentage of total production over the last twelve months was closest to: A) 23; B) 23.5; C) 24; D) 24.5. 

This is a standard DCA problem (with a few tricks). I'll post the solution later, but feel free to ask any questions/discuss in the meantime. It does take some time to get used to the format and equations in the new SPE Reference.

Gas Reservoirs: 2021 #20

True statements about drive mechanisms include (select any that apply):
__ From a reservoir viewpoint, dry and wet gas cannot be treated similarly in terms of production characteristics.
__ From a reservoir viewpoint, dry and wet gas cannot be treated similarly in terms of pressure behavior.
__ From a reservoir viewpoint, dry and wet gas cannot be treated similarly in terms of recovery potential.
__ A retrograde-condensate gas reservoir initially contains a single-phase fluid, which changes to two phases (condensate and gas) in the reservoir when the reservoir pressure decreases.
__ The term “condensate” is often applied to light hydrocarbon liquid produced from a gas well.
__ The term “condensate reservoir” should be applied only to situations in which condensate is actually formed in the reservoir because of retrograde behavior.
__ For both wet and dry gasses, reservoir engineering calculations are based on a single-phase reservoir gas.
__ The effect of a weak to moderate waterdrive is often difficult to detect from a simple p/z plot.
__ Depletion behavior of retrograde-condensate reservoirs can be handled through the p/z analyses with the caveat that the z-factor must be the two-phase z factor.

Once again, remember the provided Reference Guide will offer no assistance on these types of word problems. Most of these word-style questions will come from the SPE Handbook Series (as well as the SPE Textbook Series (TS). So a good study plan is to read the parts of the HS you lack experience with.

Click the button for the answer, along with commentary and SPE references sourced. Feel free to ask questions in the comment box below.

__ From a reservoir viewpoint, dry and wet gas can be treated similarly in terms of production characteristics (HS5 P981).
__ From a reservoir viewpoint, dry and wet gas can be treated similarly in terms of pressure behavior (HS5 P981).
__ From a reservoir viewpoint, dry and wet gas can be treated similarly in terms of recovery potential (HS5 P981).
 X A retrograde-condensate gas reservoir initially contains a single-phase fluid, which changes to two phases (condensate and gas) in the reservoir when the reservoir pressure decreases (HS5 P981).
 X The term “condensate” is often applied to light hydrocarbon liquid produced from a gas well (HS5 P982).
 X The term “condensate reservoir” should be applied only to situations in which condensate is actually formed in the reservoir because of retrograde behavior (HS5 P982).
 X For both wet and dry gasses, reservoir engineering calculations are based on a single-phase reservoir gas (HS5 P983).
 X The effect of a weak to moderate waterdrive is often difficult to detect from a simple p/z plot (HS5 P1022).
 X Depletion behavior of retrograde-condensate reservoirs can be handled through the p/z analyses with the caveat that the z-factor must be the two-phase z factor (HS5 P1024).

Gas Reservoirs: 2021 #19

A gas reservoir produced 1 MMscf gas and 13 MSTB water. The current and initial gas formation value factors...reservoir modeling predicts two equally possible scenarios for water influx...The initial gas in place (MMscf) is most likely closest to: A) 27.1 B) 30.1 C) 33.1 D) There is likely not any water influx. 

This problem is fairly simple; just watch the units. It try to crank these out quickly and let the chips fall where they may, so it wouldn't surprise me if I had an error floating around on this one. Just remember on gas reservoir problems, 90% of the errors are units, and the last 10% are just misreading the problem.

Anyway, I'm posting #19 to address any questions, or even to take suggestions on how it could be modified to better prepare one for gas reservoir problems.

Klinkenburg: 2021 #18

This is a fairly tough word problem, and it shows how difficult reasonable questions can be when mixed in with so many different subjects on an 8 hour exam. To properly prepare one would have to read hundreds of pages out of the Handbook Series, have a very good memory, and then hope for the best. 

This problem, in contrast, culls any direct SPE quotes that could "reasonably" be asked on the subject. So: simply read this problem set and thus get a basic understanding and be fully armed with little effort. 

Make a point to avoid getting bogged down on the details, details that simply cannot be reasonably asked on this type of exam.

Resource Question

Question: I found your blog, thank you for all the information and practice questions and guide work. I am overwhelmed so far in my quest to study for the exam. Seeing your suggestions that I read SPE Textbook Series #1, #2, #12, and #4 and the 7 volume Petroleum Engineering books makes me think I need to start with a prep course to hone in on how to study efficiently. Based on commenters or private correspondence do you know which prep course is best suited for the newer CBT test?

Answer: I would merely 1) do as many practice problems as possible using the SPE Exam Resource. Once you've done that, you will have a solid idea of your weak areas and what resources you need to get. Only then would I consider taking a course as needed. Regarding which course, I think that depends on your specific weak areas. But since you will need to do practice problems anyway, start there.